Technical Information

KCETAŞ AUTOMATIC METER READING SYSTEM (OSOS)

Our company, which closely follows technological developments, started the "Automatic Meter Reading System Project", one of the most important pillars of the electricity distribution and supply sector, within the scope of the 2003 investment program. Based on the importance of measurement and instant evaluation within the framework of the Balancing and Reconciliation Regulation, Demand Estimations Regulation and similar regulations published by the Energy Market Regulatory Authority, and the rapid and complete transfer of data to PMUM (Currently EPİAŞ), our company has achieved a first in Turkey in the electricity distribution sector with the "Automatic Meter Reading System Project". In the first phase of the project, 95 high-consumption subscribers were included in the automatic meter reading system through the energy entry points offered to the distribution system from our Company's TEİAŞ substations. In this period, PSTN and GSM were used as communication infrastructure, due to the technological possibilities and conditions of that day. In addition, within the scope of this project, energy analyzers were placed at a total of 61 measurement points, including TEİAŞ substations, allowing the energy presented to the distribution system and delivered to consumers to be examined and analyzed in terms of quality. The first phase of the project was completed in a short period of 6 months in 2004 and put into operation. Automatic Meter Reading System works in harmony with the Subscriber Information Management System used within our company, thus automatic invoicing can be made and work orders for the field are automatically generated. In addition, with the web application of the system, daily invoicing index values and hourly consumption values can be presented to all consumers within the system over the internet.

In 2005, the work of adding 380 high-consumption customers to the system using GPRS-Internet communication technology was completed, and as of the end of 2006, 380 high-consumption subscribers were included in the automatic meter reading system with the second stage project.

In the third stage of 2007, all necessary infrastructure work was completed to include 1000 high consumption subscribers within the scope of automation and field work was carried out in 2008. Thus, as of the end of 2008, the total number of high-consumption private subscribers connected to the Automatic Meter Reading System reached 1500.

In 2010, 1,500 subscribers with high consumption special subscriber features were included in the Automatic Meter Reading System, increasing the total number to 3,000. Within the scope of these three expansion projects, the communication infrastructure was preferred as GPRS.

In 2011, the automation application infrastructure works for residential meters were completed and the tender was made. Approximately 1700 residential subscriber meters fed through two selected distribution transformers were commissioned using PLC-GPRS communication infrastructure. Features such as remote cutting-on and communication via PLC were preferred in the meters used within the scope of this project.

In 2012, the necessary work to include general lighting meters and transformer main meters in the remote reading system was completed, the tender was made, and in 2013, the field installation of approximately 6000 meters was completed and included within the scope of OSOS. With this study, in addition to consumption information from the transformer main meters, network parameters and some energy quality data began to be obtained.  In this way, it is possible to provide energy to subscribers within our distribution region with better quality and minimal interruption.

With the studies carried out in 2014, approximately 80 private subscribers and all of the Unlicensed Energy Production Plants that became operational during the year were included in the Automatic Meter Reading System for private subscribers. In addition, preliminary studies for the private subscribers OSOS system expansion project have been completed and the tender phase has been successfully concluded. With the planned expansion work, it is planned that 3000 more special subscribers will be included in the system and most of the subscribers with reactive responsibilities in our distribution duty area will be included in OSOS.

In 2015, the Automatic Meter Reading System expansion project, which was planned and tendered in the previous year, was completed and 3000 high consumption private subscribers were included in the system. After this study, the number of measurement points in the OSOS system for private subscribers increased to 6350. During the installation phase, the measurement circuit elements of the subscribers were also checked and the necessary measurement circuit elements and measurement panels were replaced. In addition, all sales and control meters of Unlicensed Electricity Generation Facilities that came into operation in 2015 have also been included in OSOS.

As of 2016, the total number of measurement points in the KCETAŞ OSOS system has exceeded 14,000. Necessary technological research is being carried out to spread the OSOS System to all subscribers, and developments in the world in this regard are closely followed. Joint projects are also being developed with R&D companies regarding new meter reading techniques.

With the newly added measurement points in 2017, the number of OSOS measurement points has exceeded 14500. Within the scope of the R&D projects carried out, studies were carried out on wireless data transfer so that meter data can be read remotely. It is planned to transfer the meter data of residential subscribers using wireless communication at the substation, through a device to be developed as a result of the studies, and send it to the Company database from there. In addition, within the scope of OSOS expansion studies, meter communication tests were carried out using 3G communication infrastructure for the first time. The installation of newly purchased subscriber OSOS meters started at the end of 2017.

In 2018, within the scope of OSOS R&D studies, a special communication device was developed for one of the most used meter brands in our distribution duty area. With the device, the data taken from the optical ports of the meters were sent to the data collector in the substation via wireless communication network. The developed device has both an optical communication port and a wireless communication module. The modules create a mesh network within themselves and the meter data reaches the collector by jumping over other modules. Data is pulled into the OSOS software with an external modem through the communication port on the collector. These modules have been installed on approximately 800 meters and communication tests are being carried out.   

Again in 2018, approximately 1000 meters were installed for General Lighting and high consumption subscribers and the total number of OSOS measurement points reached 15250. In the same period, OSOS software changes were completed and meter data was collected with a more up-to-date software. Tablet computers were distributed to field teams on the new OSOS software, and field teams began to enter the transactions performed in the field into the database and perform communication tests remotely.

With the new software, integrations have been made with both in-house software and other Institutions, and meter data has begun to be shared live with many systems and Institutions.

Hourly data of the settlement and withdrawal units within our distribution region are delivered to the EPİAŞ Market Management System in a timely and complete manner, thanks to the Automatic Meter Reading System. Again, thanks to OSOS, energy purchase amounts can be determined and Demand Forecasts can be made hourly every day, and the data that will form the basis for the Day Ahead and Intraday Market is made available.

In alternating current, transformers are devices that change the voltage and current values ​​of electrical energy according to need, provided that the power remains constant. In terms of their purpose and construction, they are:

Power (Distribution) Transformers
Measurement (Current and Voltage) Transformers
Special Purpose Transformers

When an alternating current is applied to the primary windings of a transformer, a magnetic flux begins to circulate in the iron core within the coils. This flux cuts the secondary winding located on the leg of the iron core, induced a voltage through magnetic induction.

There is no electrical connection between the primary and secondary windings.

The operating principle of three-phase transformers is similar to that of single-phase transformers.
There is a 120° phase difference between the windings of the three phases.

In transformers, voltages are directly proportional to the number of turns in the windings, while currents are inversely proportional. This ratio is also the no-load conversion ratio in transformers.

Components of Distribution Transformers;

Iron Core; Provides magnetic flux.
Primary Windings; Thin and with many turns, it is the MV input part of the transformer.
Secondary Windings; Thick and with few turns, it is the LV output part of the transformer.
Insulating Oil; The windings provide insulation and cooling between the windings and between the housing and the tank.
Main tank; This is the section where the windings, core, and oil are located.
Reserve tank; This is the expansion and reserve oil tank.
Oil level indicator; This is for checking the reserve oil service.
Radiator; This provides cooling for the transformer oil.
Wheels; These are used to transport the transformer.
MV – LV bushing; These are the connection terminals for the MV and LV phases.
Arc horn; These are elements that protect the transformer in case of a voltage surge in power transmission lines.
Thermometer; This shows the temperature of the transformer.
Voltage tap switch; This is used to adjust the MV voltage level.
Carrying hooks; It is used to lift the transformer during assembly and disassembly.

TRANSFORMER CONNECTION TYPES

Delta Connection

Features

One end of each phase's sub-windings is connected to each other, and the phases are applied to the other ends. The connection point is called the star point or neutral point.

STAR CONNECTION

 

FEATURES

One end of each phase's windings is connected to each other, and the phases are applied to the other ends. The connection point is called the star point or neutral point.

TAP CHANGING IN TRANSFORMERS

When the supply voltage value (primary voltage) of transformers is changed, the secondary output voltage must be kept constant. Because providing customers with the nominal secondary voltage is essential for operation. Therefore, tap-changing mechanisms have been added to distribution transformers to provide the nominal secondary output voltage in response to varying primary voltages. This voltage adjustment system, located on the primary windings, is used when the transformer is unloaded. They are usually manufactured in three stages. The principle is to change the transformer's transformation ratio by removing and adding winding segments from the primary windings. Example; (MV – LV)
1st Stage 33,000 Volts
2nd Stage 31,500 Volts – 400 Volts
3rd Stage 28,500 Volts

Let N1=3000 Windings
Let N2=40 Windings

1. CASE: When the transformer's main switch output reads 420 V, to which stage should the transformer be set?

Accordingly, the transformer will be set to the 2nd stage.

2. CASE: When the transformer's main switch output reads 380 V, to which stage should the transformer be set?

– Accordingly, the transformer will be set to the 3rd stage.

3. CASE: When the transformer's main switch output reads 440 V, to which stage should the transformer be set?

It needs to be switched to the next stage.

– Accordingly, the transformer will be switched to the 1st stage.

NOTE: As a rule, if the voltage in the transformer distribution panel is low, the transformer stage will be switched to the stage with the lower voltage; if the voltage is high, the transformer stage will be switched to the stage with the higher voltage.

OPERATIONAL GROUNDING IN TRANSFORMERS

Grounding the star point of transformers is called operational grounding. It is very important to perform operational grounding on transformers. In operational grounding, the grounding resistance should not exceed 5 ohms. Therefore, humid and red soil areas are chosen. Rocky, clay, and sandy soils are not preferred. During the village electrification period, operational grounding was done to the first pole. In large city transformers, a channel 80 cm deep and 20 m long is opened from the LV panel to a humid place with good soil. A trench at least 150 cm deep and 100 cm long is dug at the end of the canal. A strip of NYY cable with a cross-section of 50 mm² or equivalent is laid in the opened channel and securely fastened to a galvanized iron plate, usually 100 x 50 cm in size and 3 mm thick, with at least two bolts of 1.5” thickness, and the connection points are also soldered. Then, the grounding electrode is placed lengthwise and vertically in the hole. The hole is filled with soil and the soil is thoroughly compacted. Thus, the grounding plate is buried in the ground. In balanced loads, since the vector sum of the currents passing through the phases is zero, the current passing through the neutral line will also be zero. In a 3-phase current, there is a phase difference of 120Ω between the phases. The vector sum of the currents Ia and Ic is equal to the current of a single phase. Accordingly; Ia + Ib + Ic = 0. In unbalanced loads, since the vector sum of the currents passing through the phases cannot be zero, a certain current will pass through the neutral line. For example, in a 3-phase current, the third phase is 100 Amperes from two phases. When a 120 Amp load is drawn, the vector sum of the currents passing through the phases will be 100A + 100A + 120A = 20A, so it will draw a 20A current from the neutral line. This current passing through the neutral line will cause a voltage drop of that proportion. For this reason, in long lines, grounding is done at intervals to reinforce the neutral line and prevent voltage drop. Protective Grounding in Transformers: It is defined as connecting the metallic parts of the installation, which are not under voltage under suitable operating conditions but are expected to become energized in case of a fault, to the ground via a conductor, and it must be below 20 ohms. High Voltage Bushing and Arc Horn: The distribution transformer also has an arc horn on the high voltage bushing on the primary side. The spacing between these arc horns should be checked to ensure it conforms to the standard, and if not, it should be adjusted. Otherwise... This causes the transformer to malfunction and burn out.

Operating Voltage	Arc Neck Jump Gap
6.3 kV	6 cm
10 kV	8.6 cm
15 kV	11.5 cm
30 kV	22 cm

THERMAL PROTECTION
One of the factors that causes a decrease in the insulation value in transformers is temperature. 90°C is accepted for the insulation oil and 95°C for the winding.

Accordingly, transformers should not be operated at temperatures exceeding 95°C. The protection device used for this purpose is called THERMAL PROTECTION.

If the oil temperature reaches 70°C, the alarm auxiliary relay will activate. This In this situation, first the buzzer rings, then the "THERMAL ALARM" light signal appears on the control panel. If the temperature reaches 85°C, the tripping auxiliary relay activates. The transformer is taken out of service. In this case, the cause of the temperature increase should be investigated, cooling should be done, and the transformer load should be checked, as the transformer will not overheat under normal operating conditions. TTR and INSULATION TESTS IN DISTRIBUTION TRANSFORMERS
Purpose of TTR Test: The TTR test is performed to determine the accuracy of the ratio between the windings of the transformer.
Purpose of Insulation Test: It is performed to detect short circuit faults between the windings and between the windings and the tank.
Insulation test between MV and LV windings: The primary and secondary windings are short-circuited separately. The (+) end of the Megger is attached to the primary windings, the (-) end to the secondary windings, and the ground end of the Megger is attached to the body, and the test is performed at the 5000 V range. The following tests are performed:
Primary - Body Insulation Test: The (+) end of the Megger is connected to the primary winding, the (-) end to the body, and the ground end of the Megger to the secondary windings, and the test is performed at 2500 V.
Insulation Test between LV Windings and Body: The (+) end of the Megger is connected to the secondary windings, the (-) end to the body, and the ground end to the primary windings, and the test is performed at 1000 V.
NOTE: Testing cannot be performed on LV secondary windings at 2500 - 5000 V, otherwise the LV windings may burn out.

DC RESISTANCE WITH OHMMER

Whether there is a short circuit between the MV and LV windings is checked by measuring with an ohmmeter.
Whether there is a leakage between MV and body is checked by measuring with an ohmmeter.
Whether there is a leakage between LV and body is checked with an ohmmeter. Checked by measuring with an ohmmeter.
Whether there is a break in the primary and secondary windings is checked by measuring with an ohmmeter.

CURRENT TRANSFORMERS
A current transformer is a measuring transformer that reduces the primary current within a certain ratio under normal operating conditions and has a phase difference of zero degrees between the primary and secondary currents.
It also provides insulation of relays and measuring instruments from the high-voltage system. The windings connected in series to the circuit are called primary; the windings that feed the relays and measuring instruments are called secondary.
Dividing the primary circuit current by the secondary circuit current indicates the transformation ratio of the current transformer.

Example:
In a current transformer with a label that says 100/5 A, the number 100 represents the primary current and the number 5 represents the secondary current.
Accordingly, the transformer's transformation ratio is determined by measuring with an ohmmeter. rate

Ground Relay Adjustment Levels

CURRENT TR.	MULTIPLIER	0.9	1.5	2	2.5	3	3.5	—
10/5	2	1.8	3	4	5	6	7	ampere
15/5	3	2.7	4.5	6	7.5	9	10.5	—
20/5	4	3.6	6	8	10	12	14	—
30/5	6	5,4	9	12	16	20	24	—
40/5	8	7.2	12	16	20	25	30	—
50/5	10	9	15	20	25	30	35	—
75/5	15	13.5	22.5	30	37.5	45	52.5	—
100/5	20	18	30	40	50	60	70	—

Table 1

Overcurrent Line Currents as Current Transformer Multiplier

CURRENT TR.	MULTIPLIER	2	3	4	5	6	7	—
10/5	2	4	6	8	10	12	14	ampere
15/5	3	6	9	12	15	18	21	—
20/5	4	8	12	16	20	24	38	—
30/5	6	12	18	24	30	36	42	—
40/5	8	16	24	32	40	48	56	—
50/5	10	20	30	40	50	60	70	—
75/5	15	30	45	60	75	90	105	—
100/5	20	40	20	80	100	120	140	—

Table 2

EXAMPLE:
There are transformers with an installed power of 800 kVA on a high-voltage transmission line. The maximum power utilization factor (diversity) of the line is determined as 62.5%. Determine the current transformers to be used for 34.5 kV and 15 kV.

Solution:

The maximum power drawn continuously Power;
N=%62.5×800 =500kVA

Line current according to 34.5 kV voltage;
I1=500/34.5×1.73=8.37Amp.

Line current according to 15 kV voltage;
I2 =500/15×1.73=19.2 Amperes

Since the line current is calculated as 8.37 Amperes for 34.5 kV, the maximum value in Table 1 is 10 Amperes. The current transformer equivalent of 10 Amperes is 20/5, and the overcurrent relay adjustment step equivalent is that subsequent steps cause the current transformer to operate above its rated current. Also, since current transformers are connected in series with the circuit, they are affected by the short-circuit currents of the line, and thermal and dynamic forces can damage the current transformer.

In this respect, a sensitive In addition to the possibility of overcurrent adjustment, current transformers must also withstand short-circuit currents. In Table 2, the 15/5 current transformer provides both a wider adjustment range for the overcurrent relay and can withstand thermal and dynamic installations in case of line short circuits. When a 15/5 current transformer is selected, the relay's step can handle a line current of 9 Amperes, and it also provides the grounding relay (Table 1) with an adjustment range from 2.7 Amperes to 10.5 Amperes of ground leakage current. If the ROI is 15 kV: In the example above, if the overhead power line and ROI are 15 kV, each line current was calculated as 19.2 Amperes. Although the closest larger value in Table 2 appears as 20 for the 5 adjustment steps of the 20/5 current transformer, the most suitable current transformer selection is 40/5, and the adjustment step will be 3. The grounding relay (Table 1) will also be 7.2... Fault current adjustment capability between 28 amperes is provided.

As seen, the sensitivity of overcurrent and ground relays depends on the selection of the current transformer. However, when selecting a current transformer, one should choose one that will be least damaged by short-circuit currents and thermal/dynamic effects on the line.

Note: In case of a fault in the current transformer; ensure that the secondary connections are not loose, and ground it by short-circuiting to prevent dangerous voltages from occurring.

VOLTAGE TRANSFORMERS

A voltage transformer is a transformer that reduces high voltage within a certain ratio and has a phase difference of approximately zero degrees between the primary and secondary voltages. It enables relays and measuring instruments to operate at low voltage.
The secondary side (v is small) of the voltage measuring transformer must always be grounded. Grounding is mandatory to ensure the safety of life and property against dangerous contact voltage. Fuses are installed on the primary and secondary sides (short-circuit protection). A fuse must absolutely not be installed on the ground line.

not included.

It is the ratio of the nominal primary voltage to the nominal secondary voltage written on the label of the voltage transformer.

EXAMPLE: The transformation ratio of a voltage transformer with a label that says 34.5/0.1 kV

Primary rated voltage is generally 3.3 – 6.3 – 10.5 – 15.8 – 31.5 – 34.5 – 154 – 380 kV.
Secondary rated voltage is 100 – 110 – 115 – 120 Volts or the √3 of these voltages in the standards.
The voltage generally used in our system is 100 Volts.

Phase-to-Ground voltage transformer (with one bushing)
(Generally in 154 and 380 kV systems) (Used.)
Phase-to-Phase voltage transformer (two bushings)
(Manufactured up to 35kV.)
In medium voltage systems, there are reverse voltage transformers with a 220 Volt winding used in substation buildings.
This winding is used for lighting the substation building, supplying the circuit breaker motor, or supplying the rectifier.

Note: In case of a fault in the voltage transformer; ensure that the secondary connections are not loose, and open circuit to prevent dangerous voltages from occurring.

A capacitor simply consists of two large plates placed face to face, close to each other. If we connect these plates to the + and – terminals of a battery, a field will arise between the plates. As long as the plates are close to each other, the field lines (Figure 1) will be between the two plates, but as the distance between the plates increases, the field lines will move out a little more and spread into the space. (Figure.2)

According to the basic principles of electrotechnics, there are fewer electrons in the (+) pole of a battery and more electrons in the (-) pole.
This difference in electron loading will be transferred to the (+) pole from plate 1 and some electrons from the (-) pole will be transferred to plate 2 in order to ensure mutual balance in the battery by connecting the battery to the plates.

Thus, the electric current we know will be born. This current will of course flow until the number of electrons in the poles of the battery is equal. This electron transport event is called "charging the capacitor".

If we separate this capacitor from the battery and connect it with a wire, the transport from the plate with many electrons to the plate with fewer electrons begins. Of course, until the number of electrons in the two plates is equal to each other, it is brought to the state in which it was first connected.

I wonder what we will see if we do the same experiment with an alternating current?
An alternating voltage was changing its direction at certain time intervals. Then, the pole with fewer electrons will change to a pole with more electrons, and on the other hand, the pole with more electrons will change to a pole with fewer electrons, depending on the network frequency. Accordingly, logically, the capacitor connected to such a network will have to keep up with this pole change. In other words, electrons will be constantly absorbed from one plate, electrons will be sent to the other plate, and after a while, with the frequency of the network, electrons will be sent in the opposite direction and electrons from the other. will be absorbed. Thus, the continuous flow of electrons will change its direction. So; alternating current will flow. We are witnessing two important events here:

If we examine what the value of this resistor depends on, we see that according to Ohm's law, the greater the current at a certain voltage, U = I.R, the smaller the value of the resistance in this circuit. The same idea can be said for the capacitor as follows.

The larger the opposing plates in a capacitor, the greater the current flows. Because the larger plates are, it will correspond to the number of electrons moving from one to the other. The majority of these electrons moving in a certain time unit means a large current is passed. This corresponds to the smallness of the resistance in Ohm's law. But one important point should not be forgotten here. Because the higher the frequency of the applied alternating current, the frequency of electrons coming in and out in a certain time unit will increase, which means the current grows.

It is possible to draw the following important conclusion from the above explanations.
The higher the surface of the capacitor's plates, or rather the "capacity" and the applied frequency, the smaller the resistance of this capacitor in alternating current. In other words, it is said that the resistance of the capacitor in alternating current changes with the frequency. Of course, not only the size of the surface of the plates but also the distance between them and the type of insulation play a role in capacitors. The closer the distance, the greater the capacity. The effect of the insulating material is explained by a constant number, the "dielectric constant". The height of this constant corresponds to the size of the capacity of the capacitor.

It is certain that there will be an energy deposit inside a capacitor filled with direct current, and a voltage and current are needed to fill it. The magnitude of the applied voltage is important in discharging this energy and filling the capacity of the capacitor, because the greater the filling voltage, the greater the current will be. The capacity of capacitors is called "farad", one millionth of it is called "microfarad", and one millionth of a microfarad is called "picofarad".

DEPENDING ON THEIR STRUCTURE, POLLS CAN BE GROUPED UNDER 3 TITLES;

• Tree
• Iron
• Concrete

WOOD POST

Wooden poles are used in distribution networks even in advanced countries due to their positive properties. They are preferred because they are economical, easy to transport, and require short installation and assembly times.

Although weak peak forces are seen as a disadvantage, the application of lintel and/or double wooden poles is mostly done in places where linting is not possible.

Wooden poles are treated against harmful parasites and insects to increase their lifespan. In addition, it is made resistant to moisture and moisture by tarring. Wooden poles are called LIGHT, MEDIUM and HEAVY depending on their diameter. 9 - 10 m wooden poles are used in the LV Network. 11 m wooden poles are used in MV+LV networks. 12 m wooden poles are used in ETL.

For example: It is understood that the 9 – H type pole is 9 meters long and a light class wooden pole.

IRON POSTS
They can be manufactured as painted welded or galvanized - with galvanized bolts. Angle iron and profile iron in various sizes are used in the manufacture of iron poles. Profile irons are used in the manufacturing of type A painted welded iron poles, and these types of poles are A.G. and O.G. +A.G. It is used in electrical networks. Iron poles used as type A are named as 8I-10I – 12I – 6.5U – 8U – 12U. For type A poles used in short lengths, the above nomenclature also includes a lower case (k). Here I or U refers to the shape of the iron profile used in the manufacture of the A type pole and the height of the profile in numbers.

• Angle irons are used in the manufacturing of painted welded cage poles and galvanized - galvanized bolted poles of all types and sizes.
• The sign (') is used when iron poles made of profiles and angle iron are used in O.G + L.G. electrical networks.
• Iron poles are longer lasting than wooden poles and much lighter than concrete poles. However, maintenance and operating costs are much higher than concrete poles.
• A Type Iron Poles: They are used in LV and MV+LV networks.
• Cage Type Iron Poles: They are used in LV, MV+LV and ENH.

CONCRETE POSTS;

Poles made of concrete obtained by mixing cement, water, sand, gravel and additives in appropriate proportions, high-strength pre-stressed steel wire and centrifugal method are called SBA Concrete poles.

The most important advantage of concrete poles compared to iron poles is that they are less affected by weather conditions and especially harmful gases and vapors in industrial areas.

Concrete poles are manufactured in two different features according to buckling load. Those with low buckling loads are used in LV and MV+LV electrical networks, and those with high buckling loads are used in places that comply with the label values ​​on the ETL. On the printed label of the concrete pole, there is a danger of death sign painted in red and values ​​indicating the peak force and length of the pole. For example, a pole with the numbers 9,30 and 600 on its label is understood to be 9.3 meters long and has a peak force of 600 kg.

It is used according to the label values on concrete poles. There are concrete poles used in LV and MV+LV networks. The connection of concrete poles to the ground is made through grounding sockets.

POST FOUNDATIONS

• Foundations are made in accordance with Article 56 of the "Electric Power Current Facilities Directive".
• For wooden poles, starting from the ground, the depth will be 130 cm for poles up to 8 meters high, and 10 cm will be added to this length for each meter exceeding 8 meters.
• For iron poles, the minimum depth will be 150 cm according to the minimum height.
• For concrete poles, the minimum depth will be 120 cm according to the minimum height.

They are system elements used to safely turn on and off loaded circuits.

Ke E M	: Breaker : Electrical interlocking : Mechanical interlocking
a) b) c) d)	Oil breakers. SF6 gas breakers. Vacuum. Air breakers.

EXTINGUISHING THE ARC IN OIL BREAKERS
An arc occurs between the opening control coming to the breaker and the moving contact leaving the fixed contact. It enters the arc cells on the arc path, and some burning occurs in the oil due to the heat effect of the arc. The gas produced by combustion goes to the pressure balancing chamber within the extinguishing cell. At this moment, the pressure occurring inside the breaker pushes the oil into the arc oil extinguishing cell and extinguishes the arc.

PROPERTIES OF SF 6 GAS
a) It is a colorless, odorless and non-poisonous gas.
b) It has very high dielectric strength properties.
c) It does not burn.
d) SF 6 is in gaseous state under normal atmospheric conditions. It is 5 times heavier than air under 1 bar pressure and 200 C.

EXTINGUISHING THE ARC IN SF 6 GAS BREAKERS
PUFER SYSTEM:
When the breaker is tripped, the arc goes out by spraying the pressurized SF 6 gas trapped under the contact onto the arc, thanks to the piston moving when the movable contact comes down.

FULARK SYSTEM:
In this system, the pressurized SF6 gas in the cutting cells is extinguished by filling the space vacated by the moving contact and suffocating the arc.

STRUCTURE OF VACUUM BREAKERS
It consists of two mutual disc-shaped copper chrome alloy contacts, one of which is fixed inside the vacuum cell and the other is externally driven, and a ceramic cylinder with an air-emptied container. They are made of pressure-resistant fiber porcelain.

EXTINGUISHING THE ARC IN VACUUM BREAKERS
When the opening command comes to the breaker, the contacts begin to separate from each other, the arc continues until the current between the two contacts reaches zero, and when the current reaches zero point, the arc goes out. It consists of two COPPER-CHROMIUM alloy contacts in the form of opposing discs, one of which is fixed and the other is moved from outside, inside the vacuum cell, and a completely air-emptied container and a CERAMIC cylinder.

There is a metal bellow, one end of which is connected to the shaft of the movable contact and the other end to the evacuated container. This metal bellows; It provides the seal between the de-aerated cell and the outside air.

It is a system element used to safely open and close unloaded circuits.

PARTS OF THE SEPARATOR

• Chassis
• Post insulator
• Moving contacts
• Fixed contacts
• Moving contact pushers
• Mechanism and locking instruction
• Ground knife (Found on line separators.)

TYPES AND TYPES OF DISCRIMINATIONS

Types According to Where They Are Mounted (Functions)

• Line Separator, Ground Separator
• Busbar Separator, Transfer Separator,
• Bay – Pass separator, Grounding Separator,

1. Line Separators
These are the separators located at the beginning or end of the line of E.N.H. It can be turned on and off while the breaker to which it is connected is open.

2.Busbar Separator
It is the separator located between the busbar breaker and the busbar. They can be turned on and off while the bottom breaker is closed.

3. Bay-Pass Separator
It is a separator that works in parallel with the breaker in the TEK busbar system. It can be opened and closed while the breaker it is located at is closed.

4.Transfer Separator
In the double busbar system, it combines the main busbar and the transfer busbar. It can be opened and closed while the breaker it is located at is closed.

5. Grounding Switch
It ensures the connection of electrical circuits that are not under voltage to the ground. This type of separators; If there is a line separator, breaker, busbar separator, transfer separator, bypass separator, it cannot be closed without opening the other side's separator and the other party's separator, if any.

According to their structure:

• Blade Separators
• Insured Separators
• Power dividers

VARIOUS FAILURES OF DISCUTTERS

• The post insulator may be broken or cracked,
• Broken pusher arms,
• Disarrangement of fixed and moving contacts,
• Deformation of fixed and moving contacts,
• Mechanism malfunctions,
• Locking device malfunctions,
• Poor contact on ground blades

There are two types of luminaires: external and internal. Internal types are used in indoor lighting. External types are used in outdoor and road lighting. Exterior lighting fixtures radiate light into the lower half space. However, it can be divided into four separate groups according to the light distribution curve: narrow, medium narrow, wide and medium wide.

External Lighting Fixture

Placement of lighting devices in road lighting according to DIN 5044

Placing on straight roads

Placement on curves:
In curves, the distances between lamps are chosen shorter than on straight roads. In one-sided installation, the fixtures should be on the outside of the bend. The distance between the lamps should be ¾ to ½ of the distance on straight roads, depending on the radius of curvature of the road.

Figure 2 Placement of lighting fixtures at curves

a) One row pole type
b) One row pendant type lighting fixtures
c) Two row or pendant type lighting fixtures

Similar considerations apply to one-row or two-row placement along the middle of the road.

Placement at intersections: 
Intersections should be indicated by the type of lighting. For this purpose, the brightness level can be made higher (twice the highest brightness level of the intersecting roads); Special lighting fixtures can be used.

Placement in squares:
The brightness level of the squares should be at least the brightness level of the roads with the same traffic density. If there are many pedestrians in the square, the brightness level should be increased by 50%. Luminaires in squares should be placed in such a way that the transition to the roads is quick and safe.

Placement on bridges:
Since there is no ambient glare on bridges, illuminating the bridge is similar to illuminating empty roads in terms of glare hazard. It is useful to additionally illuminate the pedestrian sidewalks of bridges with a high number of pedestrian passengers.

Placement in tunnels:
Tunnels should be illuminated at least at the level of the incoming and outgoing roads. Since natural lighting is generally insufficient, they must be illuminated during the day. Undoubtedly, the brightness level in daytime lighting should be much higher than in night lighting. In long tunnels, the entrance and exit areas should be illuminated so strongly that a gradual transition is made from high-level natural lighting to low-level artificial lighting. Additionally, adding small twinkle lamps or lighting fixtures facilitates traffic flow.

Placement at railway crossings:
Railroad crossings along a track should be specially illuminated in hazardous locations. For this purpose, it is appropriate to increase the brightness level and select special lighting fixtures and special light colors.
The brightness level in road lighting should be adapted to the traffic density. For example, it would be appropriate to apply full lighting when the traffic density is high, and weak lighting when it is low. In road lighting, the illuminance level is measured on the road surface or at most 20 cm above the road.

INSULATORS

• They are used to insulate power lines or busbars from where they are fixed. They are made of materials with very high resistance to current and high temperature resistance, such as porcelain, glass, and epoxy resin.

Insulators According to Their Purpose of Use;

• They are named as support type insulator, chain type insulator, busbar support insulator, and bushing insulator. They must be used according to the operating voltage. For example, an overhead line support insulator used at operating voltages of 15 kV and below, expressed as VHD ≥ 15, cannot be used at an operating voltage of 34.5 kV.
• In insulator selection, the pollution level of the region where the line is located (seaside, iron and steel and cement factories, etc.) is taken into consideration as well as the characteristics of the line. In such areas, insulators with voltage levels higher than the operating voltage can be used, as well as fog-type insulators.

CONDUCTOR TYPES

Copper Conductors (Cu)

Conductor Cross-Section (mm2)	Continuous Current That Can Pass Through the Conductor
10	40 °C	70 °C
16	93	110
25	115	150
35	151	200
50	174	230
75	231	310
70	282	360
95	357	420
120	411	480
150	477	610
185	544	670
240	630	780

Aluminum Conductors (Al);

Standard Nominal Name	Total Cross-Sectional Area (mm2)	Current Carrying Capacity (A)
		1	2	3
Rose	21,14	110	140	150
Lily	26.66	125	160	170
Pansy	42.37	165	200	230
Popy	53.49	193	230	270
Aster	67.45	225	260	300
Phlox	84.99	262	300	340
Oxlip	107.3	305	370	400

Steel aluminum Conductors (St-Al);

Standard Nominal Name	Total Cross-Section (mm2)	Current Carrying Capacity (A)
		1	2	3
Swallow (3 AWG)	31,14	120	160	180
Raven (1/0)	62.44	195	230	280
Pigeon (3/0)	99.3	275	300	360
Hawk (477 MCM)	156.86	345	460	510
Cardinal (954 MCM)	280.84	540	670	740

Alpek Cables ;

ALPEK (Number and cross-section of conductors)	Insulated Conductors
	Distribution Line		S. Lighting
	Number X Cross-section mm2	Braided wire number	Number X Section mm2	Braided wire. ad.
1×16+25 1×25+35 1×35+50	1×16 1×25 1×35	1 7 7	— — —	— — —
3×16+25 3×25+35 3×35+50 3×50+70 3×70+95	3×16 3×25 3×35 3×50 3×70	1 7 7 7 7	— — — — —	— — — — —
1×16+25 1×16+1×16+25 3×16+1×16+25 3×25+1×16+35 3×35+1×16+50 3×50+1×16+70 3×70+1×16+95	— 1×16 3×16 3×25 3×35 3×50 3×70	— 1 1 7 7 7 7	1×16 1×16 1×16 1×16 1×16 1×16 1×16	1 1 1 1 1 1 1

FAULTS

A fault can be defined as a facility or line being out of commission or operating intermittently due to a number of reasons. Therefore, every fault must have one or more specific causes. Even if it is observed that results are obtained by only repairing the faulty parts without investigating the causes of the malfunction, the malfunction will reappear when the necessary conditions are met. The important thing is to prevent recurrence by eliminating the causes that create the malfunction. Faults must be eliminated by taking conscious and adequate precautions. Repairs carried out using uninformed, random methods and without investigating the causes only serve to increase operating costs and loss of life.

Failures generally occur due to the following reasons.

• Project errors,
• Installation errors,
• Operating errors,
• External installations,
• Manufacturing defects,
• Economic lifespan of materials and equipment.

PROJECT ERRORS
Failure to conduct proper studies during the design phase, incompatibility of projects with the application area, and other carelessness and human errors can cause failures.

INSTALLATION ERRORS
Failure to construct the facility according to the project, making project modifications when necessary, failure to discuss changes made during installation with those who designed the project, failure to install and assemble the material according to its properties, atmospheric effects during installation, and other factors can all lead to failures. Failure to consider external factors, and errors arising from inadequate attention to workmanship and other meticulous aspects can lead to malfunctions. OPERATIONAL ERRORS: Insufficient observation and inspection from the completion of the facility until provisional acceptance, operating the facility above its nominal capacity, operation by untrained and inexperienced personnel, and failure to perform necessary daily, weekly, monthly, and annual tests and periodic maintenance can all lead to malfunctions. EXTERNAL FACTORS: Failure to protect the facility from external factors (wind, snow, temperature, lightning, salt, ice, acidic, etc.) during operation, or insufficient protection, and the occurrence of external factors exceeding expectations can all cause malfunctions. MANUFACTURING DEFECTS: Regardless of how ideal the project, facility, and operation may be, poor quality materials and failure to meet standards can lead to many malfunctions and interruptions. In material selection and procurement, attention should be paid to compliance with Turkish and International Standards. Using low-quality materials and equipment for the sake of cheapness will lead to frequent malfunctions, making the cost more expensive than others. ECONOMIC LIFE OF MATERIALS AND EQUIPMENT Even if materials and equipment are manufactured according to standards, they may still malfunction after a certain period due to material fatigue and depletion, even under normal operating conditions. By constantly considering all the reasons described above and planning work accordingly, the reliability of the system can be increased to 99.9%, resulting in significant savings. Otherwise, continuous loss of life, property, and work will occur, resulting in a constantly busy employee who doesn't have time to even scratch their head due to malfunctions. This prevents the real problems from being seen, as the shortage of personnel leads to an increase in complaints and creates the image that the work has reached unmanageable levels, and it is thought that the solution will be achieved by hiring more personnel.

MANEUVERS

SEQUENCE OF MANEUVERS IN POWER INTERRUPTION AND RESTORATION

In the line maintenance industry, safely and correctly de-energizing a power line is an important issue. These tasks are performed by switchboard operators in transformer and SCADA centers, and by team leaders or responsible technicians in fault and operation departments. However, it is beneficial for all line maintenance technicians to be familiar with the maneuvers. Many work accidents have occurred to date due to a lack of knowledge on this subject.

Although maneuvers are not a complex or difficult subject, they require maximum attention and care. First and foremost, it is necessary to be determined, conscious, and calm.

The following sequence should be followed when performing a maneuver:

• First, the line to be maneuvered is identified, and important customers on that line are notified.
• The feeder circuit breaker is opened and checked.
• The feeder's busbar and outlet disconnectors are opened and checked.
• The feeder's ground disconnector is closed.
• Warning signs are hung on this circuit breaker to prevent others from closing it.
• Then, the team is notified to start their work.

The safest way to restore power to the feeder is for one of the team members to come and report that the work is finished. Accidents often occur during radio or telephone communications.

Therefore, it is more appropriate to assign specific individuals to the task of supplying and disconnecting power.

The following sequence should be followed when performing a maneuver:

• First, the line to be maneuvered is identified, and important customers on that line are notified.
• The feeder circuit breaker is opened and checked.
• The feeder's busbar and output disconnectors are opened and checked.
• The feeder's ground disconnector is closed.
• Warning signs are placed on this circuit breaker to prevent others from closing it.
• Then, the team is notified to begin their work.

The safest way to restore power to the feeder is for one of the team members to come and report that the work is finished. Accidents often occur during radio or telephone communications.

Therefore, it is more appropriate to assign specific personnel to the tasks of supplying and cutting off power.

BUSBAR SYSTEMS
Units where voltages of the same type are collected and distributed are called busbars. The energy on the busbar is distributed to customers through the outputs (feeders). Busbars are classified according to their structure: Single busbar system, Transfer busbar system, Double busbar system, Square busbar system, Triple busbar system. The single and transfer busbar systems, which are most commonly used in distribution, will be examined.

SINGLE BUSBAR SYSTEM
This busbar system consists of a single busbar and is economical because it uses fewer disconnectors and circuit breakers. However, there is a risk of power interruption when performing maintenance on feeder circuit breakers. To prevent this, a bypass disconnector is installed in place of the circuit breaker during maintenance. However, the circuit remains unprotected during supply with a bypass disconnector. A diagram related to this system is given below.

Definition of Relay: By taking the faulty area out of service as soon as possible, to keep the fault to a minimum and to prevent the previous circuit (source) from being affected by this fault.

OPERATING PRINCIPLE OF PRIMARY RELAYS

• Primary relays work according to the principle of electromagnetic attraction and repulsion. It consists of a coil, a reverse force spring, and a moving arm that does the pushing or pulling. It works with the movement caused by the pulling force of the magnetic field created by the current passing through the coil.

POSSIBLE FAILURES OF PRIMARY RELAY

• Pusher rod misalignment.
• Oxidation on moving mechanical parts.
• Current

PURPOSE OF SECONDARY PROTECTION 
It is ensured that it works by connecting it to the secondary of the current transformer. In this way, the relay is isolated from the MV and since the primary circuit current is reduced at certain rates (Current transformer conversion ratio), the current of the relay also decreases, accordingly the relay is made smaller and the operation becomes more sensitive.

POSSIBLE FAILURES OF SECONDARY RELAYS

• One of the connection cables in the AC connection circuit is disconnected and broken.
• Operation of the circuit to which it belongs as a result of the cable breaking or coming out in the DC connection circuit. (Light not on, horn not sounding, breaker not turning on, signaling not working at all).
• Short circuit in the DC Link circuit (Fuse blows).
• Failure of one of the overcurrent or ground relays.

FUNCTION OF THE RECLOSING RELAY
When the overcurrent or earth relay operates and opens the feeder breaker, it also sends a signal to the reclosing relay. The reclosing relay evaluates this signal; It causes the feeder breaker to close again at the end of the set time. According to the set number of repetitions, the breaker sends a closing command to the breaker at most 2 times after the fault.

1. GENERAL

1.1. Subject and Scope

This covers the design, manufacture, and testing of metal-enclosed LV Distribution Panels to be used to feed LV distribution networks from LV/MV Distribution Transformers.

1.2. Standards

LV within this scope.

Distribution panels and the electrical devices and materials to be used in the panel will be designed, manufactured and tested in accordance with the latest editions of the following Turkish Standards (TS) and International Electrotechnical Commission (IEC) Standards.

Other equivalent standards may be accepted. In this case, bidders shall submit an English or Turkish copy of the said standard with their bids.

1.3. Regulations

In the design and manufacture of the panels;
. “Regulations on High Current Electrical Installations”,
. “Regulations on Internal Electrical Installations”,
. “Regulations on Grounding in Electrical Installations”
the relevant provisions of the latest editions in force shall be complied with.

1.4. Operating Conditions

Unless otherwise specified in the Material List, the panels subject to the order shall be suitable for use under the operating conditions specified below. Table -1-

2. ELECTRICAL CHARACTERISTICS

Unless otherwise specified in the Material List, the Panels shall comply with the following electrical characteristics.

2.1. Rated Values ​​Table -2-

– Rated currents; Table -3a-

– The expected (prospective) highest short-circuit currents at the panel input; Table -3b-

2.2. Electrical Arrangement and Equipment

Unless otherwise specified, the panels shall be equipped in accordance with the single-line diagrams in Appendix 1, and the main and auxiliary circuits specified below shall be installed. These are:

– One Main Input,
– The number of three-phase power supply outputs specified in the single-line diagram,
– One three-phase Street Lighting Output,
– One single-phase internal power supply output,
– Measurement circuits

2.3 Types

Unless otherwise specified, panel types according to their power will be as follows.

POLE TYPE: Panel mounted on a support made of profile installed on a transformer pole.
BASE TYPE: Panel mounted on a base made of concrete or profile in external types, and on a cable channel in internal types.

3. DESIGN AND STRUCTURAL FEATURES

3.1. General

i) Design and manufacturing will be carried out in accordance with relevant standards, using the latest technical applications and the best workmanship, and safety factors will be taken into account to the fullest extent.

ii) All materials used in the construction of the panels will be suitable for their intended use and purpose, resistant to all kinds of mechanical, thermal, electrical stresses and moisture effects that may be encountered during normal operation, and will be free from any defects or malfunctions.

iii) The devices used in the panels will have the specifications stated in the specification and will comply with the relevant standards and/or technical specifications.

iv) The devices inside the panel;

v) External connection terminals will be easily accessible, and cable connections will be easy and safe to make.

vi) The panels will be installed on a carrier frame made of profile.

vii) Except for pole-mounted panels, the bottom of other panels will be open for cable entry and exit.

viii) The back of the panels will be closed.

ix) All bolts used in the manufacture of the panels will be at least 8x8 quality.

3.2. Protection Level

The panel enclosure shall provide at least the following protection levels against access to live parts, ingress of solid objects, and water ingress, according to IEC 60529.

– Indoor (internal): IP 2X
– Outdoor (external): IP 54

NOTE: Protection levels are for parts other than the base in panels with an open base.

3.3. Temperature Rise (Heating)

In the design of the panels, in the selection of conductor cross-sections and device characteristics; Temperature increases caused by external factors such as ambient temperatures and solar radiation, as well as power losses in the devices, busbars, cables, and other current-carrying parts inside the panel, will be taken into account. In the temperature rise limit control test, the temperature rise values ​​measured inside the panel will not exceed the values ​​given in IEC 60439-1, Table III. 3.4. Short Circuit Resistance The short circuit currents specified in Table 3 will be taken into account in the design of the panels and the selection of devices, and the panels will withstand the thermal and dynamic stresses that will occur at the rated short circuit currents. 3.5. Internal Arc Resistance Measures will be taken to prevent arc formation and shorten its duration inside the panel. Even in the unlikely event of an internal arc, the highest possible level of protection will be provided to protect people.

3.6. Protection Against Electric Shock

Protective measures specified in the standards will be taken to prevent accidental direct contact with live bare conductors under normal operating conditions, and to prevent harm to living beings from contact with bare metal parts that are not normally energized but may become energized in the event of a fault.

Protection measures against electric shock will include at least the following.

3.6.1. Protection Against Electric Shock Under Normal Operation

In panels, on the front face where the control is to be made, all safety measures will be taken to prevent accidental contact with live bare conductors under normal operation.

For this purpose, front covers/caps that will act as barriers/obstacles will be used.

The following can be performed by authorized personnel from the front while the panel is energized:

– Switching on and off of switching devices,
– Replacing fuse replacement elements (cartridges),
– Adjusting release valves,
– Replacing indicator and lighting lamps,
– Reading indicator instruments,

can be done without risk of danger.

3.6.2. Protection Against Electric Shock in Case of Faults

In case of faults occurring inside the panel or in external circuits, protective grounding will be provided to all bare metal parts of the panel and devices that may be under voltage, to prevent electric shock upon contact.

i) Protective Grounding; ii) The electrical continuity of the metal parts of the panel and all bare metal parts of the devices used in the panel that may be subjected to voltage will be ensured by connecting them to the grounding bar installed inside the panel using protective conductors (PE) where necessary. ii) The electrical continuity of the metal parts of the panel (doors, covers, etc.) will be ensured by connecting them to the metal parts using stainless steel bolts of at least M6 size and flexible yellow-green cables with lugs attached to both ends, connected by electrical discharge method. During this connection, the cable lug will be placed between two nuts and washers on the impact bolts.

NOTE: Using standard bolts instead of impact bolts, and bolts and nuts made of materials other than stainless steel (even if coated) will not be accepted.

iii) The electrical continuity of the protection circuit will be ensured by effective connections made directly or with the aid of a protective conductor, and the continuity of the protection circuit will not be lost for the remaining part when some devices are removed from the enclosure.

iv) If any, metal control levers and metal parts of devices will remain securely and continuously connected to the protection circuit.

v) The methods used to mechanically connect the metal parts of the enclosure will provide continuous and good conductivity and will be capable of withstanding the ground fault current that will flow. The electrical continuity of the protective circuit will be ensured by using a grooved washer.

All internal mounting construction elements, such as carrier profiles and mounting plates inside the panel, will be made of galvanized sheet metal and will not be painted.

vi) In the lower section of the panel, there will be a grounding busbar made of electrolytic copper with a cross-section of at least 20×3 mm² and coated with tin to a thickness of at least 3 microns to ensure grounding of both the protective conductors and the armored or shielded cables. The electrical continuity between the grounding busbar and the grounding terminal will be ensured in the best possible way.

vii) The conductor cross-sections to be used in the protective circuit will be calculated as specified in IEC 60439-1, Clause 7.4.3.1.7, and all parts of the protective circuit will withstand the highest thermal and dynamic stress that may occur in the event of a fault in the panel.

3.7. Clearances, Jump Spacing and Climb Distances

i) The clearances between devices in the panel shall be as specified in the standards for the devices themselves, and these clearances shall not change under normal operating conditions. The devices shall be mounted to meet the jump spacing and climb distance requirements specified in the standards, taking into account the relevant operating conditions.

ii) Approach spacings and climb distances for live bare conductors and terminals, such as busbars, inter-device connections and cable lugs, shall meet at least the values ​​specified for the devices to which they are connected. The clearances between busbars and bare connections shall not be permanently reduced in case of short circuits.

3.8. Enclosure and Components

i) The enclosure shall have the following characteristics.

– Enclosure type: Metal
– Exterior design: Cabinet type
– Mounting method: Pedestal type, Pole type
– Protection degree: As specified in Article 3.2.

ii) The basic structure (frame) of the panels shall be formed by assembling vertical and horizontal profiles made of at least 2 mm thick galvanized sheet metal with connecting elements. Doors and covers shall be made of at least 2 mm thick galvanized sheet metal and shall be mounted to the panel frame using connecting elements such as bolts and nuts. Doors and covers shall not have a load-bearing function. Joints made using welding will not be accepted.

A panel body made of bent profiles made of galvanized sheet metal will also be accepted.

3.8.1. Roof

i) In external types, the roof will have a slope of at least 50 and at most 150 degrees to allow rainwater to drain easily. A canopy will be formed on all four sides of the roof, extending outwards from the body. This canopy will have an inverted angle to prevent water from seeping in.
There will also be an additional threshold with an inverted angle to prevent water that may accumulate on the seal from draining inside when the door is opened. The door seal will rest on this threshold.

ii) In internal types, the roof will be flat in the shape of a hatch.

iii) There will be a suitable number of lifting rings/brackets on the top of the roof to allow for easy removal of the panels.

3.8.2. Doors

i) Doors will only be found on “external” type panels.

ii) Doors will be single or double leaf, hinged and lockable, depending on the width of the panel. Hinges will be concealed and inaccessible from the outside. At least 3 (three) hinges will be used per door, regardless of panel height. Hinges will not come loose when lifted from below, whether the door is in the open or closed position.

iii) Doors will have a robust structure resistant to torsion, bending and warping, and will rest on thresholds to provide a seal on the frame. The door edges will be equipped with one-piece, seamless polyurethane cast or air-cushioned rubber seals resistant to water and dust ingress, heat, and external factors, and will close against all contact surfaces on the panel. Reinforcement profiles will be fixed inside the doors to ensure the seal functions properly and the cover surface behaves planarly. iii) The doors will open at least 120° without hindering operation and, in external types, will be equipped with a wind pressure-resistant stopping mechanism that keeps them open. iv) The bottom edges of the doors will be at least 5 cm high. v) The door handles and locking mechanism will be designed to prevent rainwater and snowmelt from reaching the lock. There will also be a mechanism suitable for attaching a padlock if necessary. vi) In double-leaf doors, one leaf will overlap the other. The lower leaf will be secured by sliding it from the inside at the top and bottom points before the other leaf closes. When the upper leaf closes, its seal will press against the threshold formed by the lower cover, providing three-point (top/middle/bottom) locking.
3.8.3. Front Covers/Caps

i) A Front Cover/Caps will be located on the front to prevent direct contact with energized parts. In external types, the Front Cover/Caps will be located behind the door. The front cover/cap will prevent direct contact with energized parts and will also provide protection against arcs occurring in switching devices.

ii) Switching elements and measuring instruments other than the main switching elements (LV Circuit Breaker, Fused Load Disconnector and Switched Automatic Circuit Breakers to be used in the supply outputs) can be mounted on the front cover/cap.

iii) Front covers/caps will be hinged/bolted and when opened, the mounting and dismounting of devices located inside the panel can be easily done.

3.8.4. Ventilation

i) Sufficient ventilation will be provided inside the panel to prevent temperature increase and condensation. For this purpose, ventilation slits/holes will be provided at the bottom of the panel to allow air intake and at the top to allow air exhaust, providing the protection level specified in Article 3.2.

ii) In external type panels; removable filters will be installed from the inside to prevent dust entry through the ventilation slits/holes used for ventilation. These filters will be placed in cassettes for easy installation and removal for cleaning purposes.

3.8.5. Cable Inputs and Outputs

i) Unless otherwise specified, cable inputs and outputs in the panels will be as indicated in the table below.

NOTES

1. In internal type panels, entry to the panel will be made by cable/busbar connection to the main busbars extending up to 150 mm in height from a window to be opened on the top of the panel. The window to be opened on the top of the panel will be closed with a cover made of insulating material.
2. The bottom of panels where cable entry and exit are made from the "bottom" will be open and no glands will be installed for cable entry and exit.
3. In pole type panels, waterproof aluminum glands will be installed in the holes opened for cable entry and exit.
4. If specified in the Bill of Materials, the main entrance may be from the base.

ii) Necessary support arrangements will be provided inside the panel to prevent damage to the connection terminals by the busbars and cables used for external connections under normal operating and short-circuit conditions.

3.8.6. Connecting the Panels to the Ground

3.8.6.1 External Type Panels;

– Base-type panels will be placed on a concrete or profile base to be constructed on-site by the BUYER. For this purpose, the bases of the panels will have 4 reinforced holes suitable for connection with M12 bolts to be used for connecting the panels to the base.

– Pole-type panels will be placed on a profile base to be constructed on the transformer pole by the BUYER. For this purpose, the bases of the panels will have 4 reinforced holes suitable for connection with M12 bolts to be used for connecting the panels to the base.

3.8.6.2 Indoor Type Panels;

Indoor type panels will be placed on the cable channel unless otherwise specified. For this purpose, the bases of the panels will have 4 reinforced holes suitable for connection with M12 bolts to be used for connecting the panels to the base.

3.9. Panel Arrangement

i) Panels will be arranged for front-facing operation.

ii) External type panels will have a door on the front of the enclosure, and all electrical connections and cable support operations will be done from the front.

iii) Internal type panels will not have a door, and all electrical connections and cable support operations will be done from the front.

iv) The operations specified in Article 3.6.1 will be performed directly from the outside of the panel for internal types, and after opening the panel door for external types.

v) Devices will be placed and connected in such a way that they will not be damaged by mutual interaction such as temperature, electrical discharges, electromagnetic fields, and vibrations that occur during normal operation.

vi) Devices and external connection terminals; The panels will be positioned so that they are easily accessible for front-facing assembly, cabling, maintenance, and replacement operations, and the control of the devices and the replacement of fuse elements will be easily performed. Sufficient space will be provided for the separation and proper connection of the multi-core cables used for external connections. vii) The open/closed positions of the Thermal Magnetic Circuit Breaker (TMC) will be marked on the front cover/case. The symbols (I) will be used for the closed position and (0) for the open position. viii) The central axes of the devices to be controlled will be at least 0.3 m high for external type panels and at least 0.4 m high for internal type panels from the base, and the external connection terminals will be at least 0.2 m high for external type panels and at least 0.3 m high for internal type panels from the base. will be.

ix) In Fused Load Disconnectors (FLDs), fuses will not be accessible unless the disconnector is in the open position. (This is not necessary for Vertical Fused Load Disconnectors.)

x) Label slots will be located on the front cover/cap for indicating the supply outputs. (This is not necessary if Vertical Fused Load Disconnectors are used for the supply outputs.)

3.10. Panel Internal Connections

3.10.1. Genel

i) Akım taşıyan parçaların bağlantıları, normal çalışmada oluşan sıcaklık artışı, yalıtım malzemesinin eskimesi, elektrodinamik zorlamalar ve titreşimlerden zarar görmeyecek, termik genleşme, farklı metaller kullanılması halinde oluşabilecek elektrogalvanik etkiler dikkate alınacaktır.

ii) Akım taşıyan parçaların bağlantıları yeterli ve sürekli bir temas basıncı sağlayacak usullerle yapılacaktır.

iii) İki cihaz arasındaki bağlantıda ek ve lehimle birleştirme yapılmayacak, bağlantılar sabit terminaller üzerinden yapılacaktır. Kullanılan iletken tipine uygun olmayan terminaller için manşon ve pabuç gibi bağlantı parçaları kullanılacaktır.

Çok telli iletkenlere sahip kabloların bağlantıları için sıkıştırmalı tipte kablo pabuçları kullanılacaktır.

iv) İletkenler, zorunlu olmadıkça, yatay ve düşey olarak, aynı yönde giden bağlantı iletkenleri yan yana ve paralel olarak döşenecek ve dönüşler daire yayı biçiminde yapılacaktır. Yalıtılmış iletkenler, çıplak iletkenlere ve keskin kenarlara değmeyecek ve uygun şekilde tespit edecektir.

v) Pano içinde kullanılacak kablolar aleve ve ısıya dayanıklı özellikte olacaktır.

3.10.2. Ana Baralar

i) Ana baralar dikdörtgen kesitli elektrolitik bakır lamalardan yapılacaktır. Nötr barası kesiti faz barası kesiti ile aynı olacaktır. En az tek hat şemalarında belirtilen kesitlerde olması koşulu ile ana bara kesiti; panodaki sıcaklık artışı, kısa devrelerde meydana gelecek termik ve dinamik zorlamalar ve titreşimlere göre imalatçı tarafından farklı kesitlerde de seçilebilecektir.

ii) Aksi belirtilmedikçe baralar (nötr barası dahil) en az 3 mikron kalınlığında kalay ile kaplanacaktır.
iii) Baralar pano tabanına paralel veya düşey konumda olacak, gerekli sayıda mesnet izolatörleri ile tespit edilecektir. Mesnet izolatörlerinin tepe kuvveti, kısa devrede meydana gelecek dinamik kuvvetlere dayanacak kapasitede seçilecektir. (Oluklu/tarak tipi izolatör kullanılması halinde bunlar mesnetleme noktalarında çift olarak kullanılacaktır.)

iv) Aksi belirtilmedikçe fazlar; R fazı L1, S fazı L2 ve T fazı L3 ile işaretlenecektir.

v) Baralara açılan delikler ve cıvatalı bara bağlantıları DIN 43673 Part 1 ve 2’ye uygun olacaktır.

vi) Besleme çıkışlarında Dikey Sigortalı Yük Ayırıcılarının (DSYA) kullanılması halinde ana bara mesafeleri, IEC 60269-2-1 AMENDMENT 2 2002-01’e uygun olacaktır.

3.10.3. Ara Bağlantılar

i) Giriş ünitesindeki cihazlarla ana bara arasındaki bağlantılar, giriş ünitesi anma akımını taşıma kapasitesine sahip olacak ve pano girişinde beklenen en yüksek kısa devre akımının termik ve dinamik etkilerine dayanıklı olacaktır.

ii) Ana bara ile çıkış ünitelerindeki cihazlar arasındaki bağlantılar, dikdörtgen kesitli veya yuvarlak elektrolitik bakır iletkenlerle veya bakır iletkenli, çok telli, yalıtılmış kablolarla yapılacaktır. Kullanılacak iletkenlerin kesitleri; panonun düzenlenmesi, sıcaklık artışları, anma akımları, kısa devrelerde meydana gelecek termik ve dinamik zorlamalar ve titreşimler dikkate alınarak, imalatçı tarafından saptanacaktır.

iii) Termik Manyetik Kesicinin (TMK) kablo ve bara bağlantılarının kolay ve sağlıklı yapılabilmesi sırasında “Uzatma Baraları”na gerek duyulması halinde, TMK imalatçısı tarafından bu amaç için üretilmiş “Baralar” kullanılacaktır.

3.10.4. Devrelerin Tanıtılması

i) Ana ve yardımcı devre iletkenleri numara, renk veya işaretlerle tanıtılacaktır. Bu işaretleme kablaj şemalarına uygun olacaktır. Tanıtma yalnızca iletken uçlarında yapılacaktır.

ii) Koruma topraklaması devresinde kullanılacak iletkenler (PE) sarı-yeşil çift renkli olacaktır.

iii) Ana ve yardımcı devrelerde kullanılacak nötr iletkenler, açık mavi renkte olacaktır.

3.11. Topraklama Terminali

Panonun dış topraklama sistemine bağlantısı için panonun alt bölümünde, pano gövdesine elektrik deşarjı yöntemi ile irtibatlandırılmış en az M12 ölçüsünde paslanmaz cıvatadan bir topraklama terminali bulunacaktır. Topraklama iletkeninin bağlantısı için iki adet somun ve yaylı rondela terminal üzerine takılmış olarak pano ile birlikte verilecektir. Topraklama terminali toprak işaretiyle işaretlenecektir.

NOT: Direk tipi panolarda Topraklama Terminali, panonun yan dış yüzünde yer alacaktır.
3.12. Ölçü Aletleri
i) Ana Girişte;

ii) Sokak Aydınlatma Çıkışı;

• 1 adet aktif sayaç.

iii) Ana Giriş ve Sokak Aydınlatma Çıkışı devrelerinde tesis edilecek ölçü aletlerinin elektriksel bağlantıları yapılır iken;

• Akım devrelerinde : 4 mm²,
• Gerilim devrelerinde : 2.5 mm² kesitli bakır iletkenli kablolar kullanılacaktır.

iv) Ölçü Aletleri ve teçhizatına ilişkin teknik karakteristikler aşağıda verilmektedir. Malzeme Listesinde aksi belirtilmedikçe söz konusu teçhizatlar belirtilen karakteristiklere uygun olacaktır.

• Voltmetre:
• Ölçme sahası : 250 VAC ve 500 VAC
• Doğruluk sınıfı : 1,5
• Çalışma frekansı : 45-65 Hz
• Sürekli aşırı yüklenme (2 saat) : 1.2 Un
• Kısa süreli aşırı yüklenme : 2xUn
• Bağlantı şekli : Gömme tip, arkadan bağlantılı,
• Boyutları : 96×96 mm./72×72 mm.
• Standartlar : TS 5590/EN 60051-2
• Ampermetre:
• Doğruluk sınıfı :1,5
• Çalışma frekansı : 45-65 Hz
• Sürekli aşırı yüklenme (2 saat) : 1.2x In
• Kısa süreli aşırı yüklenme : 10xIn
• Bağlantı şekli : Gömme tip, arkadan bağlantılı,
• Boyutları : 96×96 mm./72×72 mm.
• Standartlar : TS 5590/EN 60051-2
• Diğer hususlar : Mekanik sıfır ayarlı, trafonun anma akımı kırmızı çizgi ile işaretli
• Aktif Sayaç:
• Nominal gerilim : 3×230/400 VAC
• Bağlantı şekli : 3 faz 4 telli.
• Doğruluk sınıfı : 0,5
• Standartlar : TS EN 61036, TS EN 60687

NOT: Malzeme Listesinde belirtilmesi halinde digital göstergeli ölçü aletleri kullanılabilecektir.

• Akım transformatörleri:
• Primer akım : Tek hat şemasına göre
• Sekonder akım : 5 Amper
• Anma Gücü : 7,5; 10; 15 VA (Yüke göre AG PANO imalatçısı tarafından seçilecektir.)
• Doğruluk sınıfı : 0,5
• Ölçü emniyet katsayısı : 5
• Sürekli termik akım : 1.2xIn
• Kısa süreli termik akım (Ith) : Pano girişinde beklenen en büyük kısa devre akımına uygun.
• Dinamik anma akımı : 2.5xIth
• Enerji Ölçer (Enerji Analizörü)

Enerji Ölçer (Enerji Analizörü) ile;

• En azından faz gerilimleri (faz-faz ve faz-nötr), faz akımları, toplam aktif enerji (kWh), reaktif enerji (kVArh), frekans, güç faktörü, aktif güç (W), reaktif güç (Var), sanal güç (VA) ölçülebilecek ve ekranında izlenebilecektir.
• Faz gerilimi, faz akımı ve toplam akımın minumum ve maksimum değerleri kaydedilecek ve istenildiğinde bu değerlere ulaşılabilecektir.

Enerji Ölçer (Enerji Analizörü) düşük güç tüketimli, AG Pano’nun çalışma koşullarında çalışmaya uygun olacak ve ölçülen parametrelerin doğruluk sınıfı 1.5’dan büyük olmayacaktır. Enerji Ölçer (Enerji Analizörü)’ne değişik oranlarda akım trafolarının bağlantısı mümkün olabilecektir.

ALICI tarafından yukarıda belirtilenlerin haricinde özellikler istenmesi halinde bunlar Malzeme Listesinde belirtilecektir.

3.13. İç İhtiyaç Devreleri

• Madde 2.3.4’de belirtilen iç ihtiyaç çıkışına aşağıdaki devreler bağlanacaktır.
  • Bir adet 1 fazlı güç prizi , (10 A kapasitede)
  • İç aydınlatma devresi.
• Bağlantılarda;
  • Priz devrelerinde en az 2,5 mm²,
  • Aydınlatma devrelerinde en az 1,5 mm² kesitli bakır iletkenli kablolar kullanılacaktır.

3.14. İsim Plakası, Ölüm Tehlikesi İhbarları ve Amblem

Panolarda aşağıda belirtilen, isim plakaları, tehlike ihbarları, bağlantı şemaları ve amblem bulunacaktır.

Plakalar ve levhalar paslanmaya dayanıklı malzemelerden yapılacak ve paslanmaz vidalar veya perçinle tutturulacaktır.

Yazılar okunaklı olacak, yazı ve şekiller dış etkilerle silinmeyecek ve solmayacaktır.

1. İsim plakası, panonun ön yüzüne, kolayca görülebilecek ve okunabilecek bir yere konacaktır. İsim plakaları, yapımcının adı ve adresi, imal yılı ve ayı, Alıcının adı sipariş numarası ve malzeme kod numarası, seri numarası, pano gücü, anma akımı, kısa devre dayanıklılığı, koruma derecesi ve standartlarda belirtilen diğer bilgileri içerecektir.
2. Pano içindeki cihazlar üzerinde, ilgili standartlarında belirtilen bilgileri içeren isim plakaları bulunacaktır.
3. Panoların kapıları üzerinde ölüm tehlikesi işareti ve uygun yükseklikteki harflerle “ÖLÜM TEHLİKESİ” yazısı bulunacaktır.
4. Harici tiplerde kapının iç yüzüne, dahili tiplerde dış yan yüzüne yapılacak bir cep içine naylon mahfaza içerisine tek hat şeması konacaktır.

3.15. Korozyona Karşı Önlemler

3.15.1. Genel

Metal bölümler korozyona dayanıklı malzemeden yapılacak ve yüzeyler korozyonu en aza indirecek şekilde işlenecektir.

Korozyona karşı aşağıdaki önlemler alınacaktır:

• Bütün yüzeyler su tutmaz şekilde düzenlenecektir.
• Metal bölümler korozyona dayanıklı malzemeden yapılacak ve yüzeyleri korozyonu en aza indirecek şekilde işlenecektir.
• Akım taşıyan parçalar demir içermeyen metalden yapılacaktır.
• Akım taşıyan ya da yapı elemanı olarak kullanılan alümınyum alaşımları korozyona dayanıklı olacaktır.
• İmalatta kullanılacak malzeme galvanik korozyona yol açmayacak şekilde seçilecek ve düzenlenecektir.
• Demirli parçalar sıcak daldırma usulüyle veya elektro galvanizle kaplanacak veya
  boyanacaktır.
• Korozyondan korunacak yüzeyler, düzgün, hasarsız, temiz ve kaplamanın ömrünü azaltan yabancı maddelerden arınmış olacaktır.

3.15.2. Boyama

Metal mahfazalı AG Dağıtım Panoları elektrostatik kaplama yöntemi ile boyanacaktır.

1. Boyanacak yüzeylerdeki, pas ve çapaklar temizlenecek, sivri kenarlar taşlanacak ve pürüzlü yerler zımpara ile düzeltilecektir.
2. Boyanacak yüzeylerdeki pas ve yağlar, boyama standartlarında belirtilen, kumlama, kimyasal temizleme, v.b metotlarla iyice temizlenecektir.
3. Elektrostatik boyamada gri renkli (Malzeme Listesinde aksi belirtilmedikçe) RAL 7032 renk kodunda) polyester tipi toz boyalar kullanılacak, kaplama 65 ± 15 mikron kalınlığında olacaktır.
4. Boyanın niteliği, boya kaplamasının kalınlığı, yüzey üzerinde homojenliği, yapışmanın kontrolu ile belirlenecektir. Ayrıca standartlarda öngörülen diğer deneyler uygulanacaktır.
5. Boya kalınlığı rastgele seçilmiş üç noktada “Boya kontrol aygıtı” ile ölçülecektir. Ortalama kalınlık yukarıda belirtilen değerler arasında olacaktır.
6. Boya tabakasının kaynaşması rastgele seçilen iki noktada TS 4313/ASTMD 3359’a uygun olarak bant yapıştırma yöntemiyle kontrol edilecektir. Deney sonucu, bu standartlarda yer alan sınıf-4’ten daha kötü olmamalıdır.

3.15.3 Galvanizleme

Galvanizleme işlemi ve galvanize edilmiş yüzeyler üzerindeki deneyler, ISO 1459, 1460, 1461 ve TS 914 standartlarına uygun olarak yapılacaktır. Aksi belirtilmedikçe galvaniz kaplama kalınlıkları TS 914 Çizelge-1’e uygun olacaktır.

Boyanamayan ve sıcak galvaniz yapılamayan küçük parçalar harici tiplerde paslanmaz çelikten, dahili tiplerde ise elektro galvaniz yapılacak veya paslanmaz çelikten olacaktır. Elektro galvaniz kalınlığı 12 mikrondan az olmayacak ve galvanizlemeden sonra uygun bir metotla pasifleme işlemi yapılacaktır.

3.16. Cihazların Ortak Özellikleri

AG PANO’da kullanılacak cihazlar (Termik manyetik kesiciler, sigortalı yük ayırıcıları, akım trafoları, eriyen telli sigortalar, ölçü aletleri, anahtarlı otomatik sigortalar, baralar, vb), varsa ALICI’nın ilgili teknik şartnamelerine yoksa ilgili TSE veya uluslar arası diğer standartlara uygun olacaktır.

Certain centers are established to deliver and distribute the produced energy to the places of use. Control and security issues of distribution from these places, which are taken as distribution centers, are important. It is necessary to comply with the regulations regarding control (command) and security in the generation, transmission and distribution of electrical energy. The force table provides the control of a facility with both locking and button operation. In dangerous situations, the power of the facility is cut off by pressing the button, and control of the energy is made optional by locking it. Ammeters and voltmeters are connected with current transformers and voltage transformers connected to the busbars. The circuit is controlled by both start and stop buttons and relays. This allows the faulty location to be isolated in case of power outages. Corner bent and DKP sheet metal are used in the construction of the panels. The panels are made to prevent substances such as dust, mud and moisture from entering into the cable entry and exit points and the cover parts.

Each voltage level is indicated in a different color on the mimic diagram to be placed on the front of the panel. Colors; 380 kV is brown, 154 kV is red, 66 kV is orange, 34.5 kV is blue, 15 kV is yellow, 10 kV and lower voltages are green, and the ground is black. Mimig diagrams; Main busbars are made of 10 mm, feeders are made of 8 mm wide and 3 mm thick fiberglass material.

Breaker and disconnector position switches will be placed on the busbars in the mimic diagrams, and there is an additional sign with a diameter of 10 mm at the intersections of the busbars and an arrow sign with dimensions of 30 * 35 * 35 mm at the outputs.
All panels are self-supporting structures.

All bolts and nuts used in the panels are made of stainless steel (Cadmium coated).

There are devices for a maximum of two feeders in 380 kV and 154 kV control panels. At voltages of 30 kV and below, there are devices belonging to 4 feeders. These; distance, overcurrent, reclosure, phase mismatch, auxiliary relays, etc. and test boxes. The 154 kV transformer feeder relay panel contains only relays for that feeder. These; overcurrent, tank protection or differential, auxiliary relays, test boxes and adapter boxes when necessary. At voltages of 30 kV and lower, there are relays for a maximum of three feeders in each relay panel. The panel includes overcurrent relay, earth relay, active and reactive meter with demand meter, recloser, auxiliary relays and test boxes. There is a grounding bar in the panels to which shielded cables will be connected.

REACTIVE POWER COMPENSATION IN PLANTS

Today, all the countries of the world are trying to ensure the most efficient use of established energy resources while looking for the most economical ways to spend their surface and underground energy resources.

Electric energy is produced as one of the most common sources of our century, and ways and calculations are made to transport it from the power plant to the smallest receiver with the least loss.

In our world, the need for electrical energy is increasing day by day and energy production is becoming more and more expensive, making it more necessary for the energy transported to be high quality, cheap and truly functioning active energy.

As it is known; If a receiver connected to the network is a motor, a transformer, or a fluorescent lamp, they draw a reactive current from the network to which they are connected to provide their magnetic fields.

Here; The energy produced in the power plant flows together to the smallest receiver under the name of active and reactive current. The reactive current, which does not do any work but only creates a magnetic field in the engine, causes unnecessary losses in the overhead line, transformer, switchboard, switches and cable.

If these losses are eliminated, the transformer will undoubtedly have a capacity to feed more motors, the disjunctor will not be chosen unnecessarily large, and the cable can be chosen with a smaller cross-section.

In addition to providing energy to the engine with less investment, less electrical energy payment will be made every month in terms of the applied tariffs.
As can be seen, at first glance, the transportation of reactive current from the power plant to the receiver seems to be a great economic loss. This energy, which is generally carried unnecessarily in energy distribution networks, is determined to be between 75-100% of the active energy carried.

By providing this reactive energy by both capacitor facilities and synchronous rotating machines from a location closest to the engine, instead of the power plant, all existing facilities from the power plant to the engine will be free from the carrying and burden of this reactive current.

Figure 1
A.G.
Power coefficient rectification principle using power capacitors

Figure 2
Compensated (1) and uncompensated (2)
power diagram of the facility

Iw = IActive
Ib = IReactive

I1 = Apparent current
I1 cos? = Active current
I1 sin? = Reactive current
All lines, facilities from the power plant to the engine:
I cos?+ I sin? = I active + I reactive
It is loaded with the sum of its current, while the motor only receives:
P =U.I.Cos?
Active energy.

Reactive power compensation is handled separately in various countries, in Germany; While 4 times more low voltage capacitors were made compared to medium voltage capacitors, in Japan; Again, in 1963, the opposite of this, and also in America, importance was given to medium voltage capacitors.
The reason for this different thought and practice can be said to be the differences in the network systems, the proximity of the power plants to the industry and buyers, and the conditions imposed on consumers by the tariffs of energy selling organizations.

TYPES OF COMPENSATION FACILITIES

1) Individual Compensation

The receivers are compensated one by one. In this way, each motor, lamp or transformer is compensated individually with capacitors of a certain power connected in parallel.

Advantages
Since the capacitors are switched on and off with each receiver, there is no need for a separate switching device, a separate fuse or discharge resistor. When large motors are switched on and off, the voltage oscillation remains at small levels. The capacitor connected to the motor must be selected appropriately. When the motor is switched off, excessive compensation may cause the motors to warn themselves. Motors are generally asynchronous squirrel cage. Required capacitor power

Figure 3

Oc (kVAr)=0,9.Io (A) UN(V).10-3

Io is the idle operating current of the motor. The reactive power drawn due to this current can be taken as constant for all loads of the motor (except starting)

2) Group Compensation

Motor, lamp and transformers that come on and off together and via the same contactor or switch can be compensated jointly. There is no need for fuse and discharge resistors.

Figure 4

If each motor in a group is turned on and off with separate contactors, it is necessary to connect the capacitors with separate contactors, but in a way that they can be entered in parallel with the motor contacts. In this case, separate fuses and discharge resistors are needed.

3) Central Compensation

If there are many motors or receivers drawing inductive loads connected to the table and they are switched on and off at indeterminate times, a compensation adjusted according to the drawn load condition can be achieved with such a system. Manual and automatic operating states always have a proper cos? It tries to keep the level. Gradual switching on and off of the capacitor creates voltage pulses with little oscillation. They are easy to project and calculate. It is easy to connect to existing facilities and installation and commissioning is possible in a very short time. It is also possible to compensate single or parallel operating transformers through collecting current transformers. The sensitivity limit of the electronic controller used and the inductive or capacitive region in which it will operate can be adjusted externally with potentiometers, providing a compensation suitable for every facility. The fact that they can be adjusted externally with tesimeters makes it easier to easily put into operation a compensation facility suitable for every facility.

Figure 5

Which type of compensation a facility should be equipped with should be selected according to the loading curves of the facility taken from time to time.