Voltage Control Method in Transmission Lines:

Practically each equipment used in power system are rated for a certain voltage with a permissible band of voltage variations. Voltage at various buses must, therefore, be controlled within a specified regulation figure. This article will discuss the Voltage Control Method in Transmission Lines by two methods by means of which voltage at a bus can be controlled.

Voltage Control Method in Transmission Lines

Consider the two-bus system shown in Fig. 5.26 (already exemplified in Sec. 5.9). For the sake of simplicity let the line be characterized by a series reactance (i.e. it has negligible resistance). Further, since the torque angle δ is small under practical conditions, real and reactive powers delivered by the line for fixed sending-end voltage |VS| and a specified receiving-end voltage |VSR| can be written as below from Eqs. (5.71) and (5.73).

Equation (5.83) upon quadratic solution can also be written as

Since the real power demanded by the load must be delivered by the line,

Voltage Control Method in Transmission Lines

Varying real power demand PD is met by consequent changes in the torque angle δ.

It is, however, to be noted that the received reactive power of the line must remain fixed at QSR as given by Eq. (5.83) for fixed |VS| and specified |VSR|. The line would, therefore, operate with specified receiving-end voltage for only one value of QD given by

Practical loads are generally lagging in nature and are such that the VAR demand QD may exceed QSR. It easily follows from Eq. (5.83) that for QD > QSR the receiving-end voltage must change from the specified value |VSR| to some value |VR| to meet the demanded VARs. Thus

The modified |VR| is then given by

Comparison of Eqs. (5.84) and (5.85) reveals that for QD = QR = QSR, the receiving-end voltage is |VSR|, but for QD= QR > QSR,

Thus a VAR demand larger than QSR is met by a consequent fall in receiving-end voltage from the specified value. Similarly, if the VAR demand is less than QSR , it follows that

Indeed, under light load conditions, the charging capacitance of the line may cause the VAR demand to become negative resulting in the receiving-end voltage exceeding the sending-end voltage (this is the Ferranti effect already illustrated in Section 5.6).

In order to regulate the line voltage under varying demands of VARs, the two methods discussed below are employed.

Reactive Power Injection:

It follows from the above discussion that in order to keep the receiving-end voltage at a specified value |VSR|, a fixed amount of VARs (QSR) must be drawn from the line. To accomplish this under conditions of a varying VAR demand QD, a local VAR generator (controlled reactive power source/compensating equipment) must be used as shown in Fig. 5.27. The VAR balance equation at the receiving-end is now

Voltage Control Method in Transmission Lines

Fluctuations in QD are absorbed by the local VAR generator QC such that the VARs drawn from the line remain fixed at QSR The receiving-end voltage would thus remain fixed at |VSR| (this of course assumes a fixed sending-end voltage |VS|. Local VAR compensation can, in fact, be made automatic by using the signal from the VAR meter installed at the receiving-end of the line.

Voltage Control Method in Transmission Lines

Two types of VAR generators are employed in practice—static type and rotating type. These are discussed below.

Static VAR generator:

It is nothing but a bank of three-phase static capacitors and/or inductors. With reference to Fig. 5.28, if |VR| is in line kV, and XC is the per phase capacitive reac­tance of the capacitor bank on an equivalent star basis, the expression for the VARs fed into the line can be derived as under.

Voltage Control Method in Transmission Lines

Voltage Control Method in Transmission Lines

If inductors are employed instead, VARs fed into the line are

Voltage Control Method in Transmission Lines

Under heavy load conditions, when positive VARs are needed, capacitor banks are employed; while under light load conditions, when negative VARs are needed, inductor banks are switched on.

The following observations can be made for static VAR generators.

  • Capacitor and inductor banks can be switched on in steps. However, stepless (smooth) VAR Voltage Control Method in Transmission Lines can now be achieved using SCR (Silicon Controlled Rectifier) circuitry.
  • Since QC is proportional to the square of terminal voltage, for a given capacitor bank, their effectiveness tends to decrease as the voltage sags under full load conditions.
  • If the system voltage contains appreciable harmonics, the fifth being the most troublesome, the capacitors may be overloaded considerably.
  • Capacitors act as short circuit when switched on.
  • There is a possibility of series resonance with the line inductance particularly at harmonic frequencies.

Rotating VAR generator:

It is nothing but a synchronous motor running at no-load and having excitation adjustable over a wide range. It feeds positive VARs into the line under overexcited conditions and feeds negative VARs when underexcited. A machine thus running is called a synchronous condenser.

Voltage Control Method in Transmission Lines

Figure 5.29 shows a synchronous motor connected to the receiving-end bus bars and running at no load. Since the motor draws negligible real power from the bus bars, EG and VR are nearly in phase. XS is the synchronous reactance of the motor which is assumed to have negligible resistance. If |EG| and |VR| are in line kV, we have

It immediately follows from the above relationship that the machine feeds positive VARs into the line when |EG| > |VR| (overexcited case) and injects negative VARs if |EG| < |VR| (underexcited case). VARs are easily and continuously adjustable by adjusting machine excitation which controls |EG|.

In contrast to static VAR generators, the following observations are made in respect of rotating VAR generators.

  • These can provide both positive and negative VARs which are continu­ously adjustable.
  • VAR injection at a given excitation is less sensitive to changes in bus voltage. As |VR| decreases and (|EG| — |VR|) increases with consequent smaller reduction in QC compared to the case of static capacitors.

From the observations made above in respect of static and rotating VAR generators, it seems that rotating VAR generators would be preferred. However, economic considerations, installation and maintenance problems limit their practical use to such buses in the system where a large amount of VAR injection is needed.

Control by Transformers:

The VAR injection method discussed above lacks the flexibility and economy of voltage control by transformer tap changing. The transformer tap changing is obviously limited to a narrow range of voltage Voltage Control Method in Transmission Lines. If the voltage correction needed exceeds this range, tap changing is used in conjunction with the VAR injection method.

Receiving-end voltage which tends to sag owing to VARs demanded by the load, can be raised by simultaneously changing the taps of sending-and receiving-end transformers. Such tap changes must be made ‘on-load’ and can be done either manually or automatically, the transformer being called a Tap Changing Under Load (TCUL) transformer.

Consider the operation of a transmission line with a tap changing transformer at each end as shown in Fig. 5.30. Let tS and tR be the fractions of the nominal transformation ratios, i.e. the tap ratio/nominal ratio. For example, a trans-former with nominal ratio 3.3 kV/11 kV when tapped to give 12 kV with 3.3 kV input has is tS = 12/11 = 1.09.

Voltage Control Method in Transmission Lines

With reference to Fig. 5.30 let the impedances of the transformer be lumped in Z along with the line impedance. To compensate for voltage in the line and transformers, let the transformer taps be set at off nominal values, tS and tR. With reference to the circuit shown, we have

From Eq. (5.75) the voltage drop referred to the high voltage side is given by

In order that the voltage on the HV side of the two transformers be of the same order and the tap setting of each transformer be the minimum, we choose

Voltage Control Method in Transmission Lines

For complete voltage drop compensation, the right hand side of Eq. (5.93) should be unity.

It is obvious from Fig. 5.30 that tS > 1 and tR < 1 for voltage drop compensation. Equation (5.90) indicates that tR tends to increase  the voltage |ΔV| which is to be compensated. Thus merely tap setting as a method of voltage drop compensation would give rise to excessively large tap setting if compensation exceeds certain limits. Thus, if the tap setting dictated by Eq. (5.93), to achieve a desired receiving-end voltage exceeds the normal tap setting range (usually not more than ± 20%), it would be necessary to simultaneously inject VARs at the receiving-end in order to maintain the desired voltage level.

Compensation of Transmission Lines

The performance of long EHV AC transmission systems can be improved by reactive compensation of series or shunt (parallel) type. Series capacitors and shunt reactors are used to reduce artificially the series reactance and shunt susceptance of lines and thus they act as the line compensators. Compensation of lines results in improving the system stability and Voltage Control Method, in increasing the efficiency of power transmission, facilitating line energization and reducing temporary and transient overvoltages.

Series compensation reduces the series impedance of the line which causes voltage drop and is the most important factor in finding the maximum power transmission capability of a line (Eq. (5.70)). A, C and D constants are functions of Z and therefore the also affected by change in the value of Z, but these changes are small in comparison to the change in B as B = Z for the nominal -π and equals Z (sinh γ1/γ1) for the equivalent π.

The voltage drop ΔV due to series compensation is given by

Voltage Control Method in Transmission Lines

Here XC = capacitive reactance of the series capacitor bank per phase and XL is the total inductive reactance of the line/phase. In practice, XC may be so selected that the factor (XL — XC) sin Φr becomes negative and equals (in magnitude) R cos Φr so that ΔV becomes zero. The ratio XC/XL is called “compensation factor” and when expressed as a percentage is known as the “percentage compensation“.

The extent of effect of compensation depends on the number, location and circuit arrangements of series capacitor and shunt reactor stations. While planning long-distance lines, besides the average degree of compensation required, it is required to find out the most appropriate location of the reactors and capacitor banks, the optimum connection scheme and the number of intermediate stations. For finding the operating conditions along the line, the ABCD constants of the portions of line on each side of the capacitor bank, and ABCD constants of the. bank may be first found out and then equivalent constants of the series combination of line-capacitor-line can then be arrived at by using the formulae.

In India, in states like UP, series compensation is quite important since super thermal plants are located (east) several hundred kilometers from load centres (west) and large chunks of power must be transmitted over long distances. Series capacitors also help in balancing the voltage drop of two parallel lines.

When series compensation is used, there are chances of sustained overvoltage to the ground at the series capacitor terminals. This overvoltage can be the power limiting criterion at high degree of compensation. A spark gap with a high speed contactor is used to protect the capacitors under overvoltage conditions.

Under light load or no-load conditions, charging current should be kept less than the rated full-load current of the line. The charging current is approximately given by BC|V| where BC is the total capacitive susceptance of the line and |V| is the rated voltage to neutral. If the total inductive susceptance is B1 due to several inductors connected (shunt compensation) from line to neutral at appropriate places along the line, then the charging current would be

Voltage Control Method in Transmission Lines

Reduction of the charging current is by the factor of (1 — B1/BC) and B1/BC is the shunt compensation factor. Shunt compensation at no-load also keeps the receiving end voltage within limits which would otherwise be quite high because of the Ferranti Effect. Thus reactors should be introduced as load is removed for proper voltage control.

As mentioned earlier, the shunt capacitors are used across an inductive load so as to provide part of the reactive VARs required by the load to keep the voltage within desirable limits Similarly, the shunt reactors are kept across capacitive loads or in light load conditions, as discussed above, to absorb some of the leading VARs for achieving voltage control. Capacitors are connected either directly to a bus or through tertiary winding of the main transformer and are placed along the line to minimise losses and the voltage drop.

It may be noted that for the same voltage boost, the reactive power capacity of a shunt capacitor is greater than that of a series capacitor. The shunt capacitor improves the pf of the load while the series capacitor has hardly any impact on the pf Series capacitors are more effective for long lines for improvement of system stability.

Thus, we see that in both series and shunt compensation of long transmission lines it is possible to transmit large amounts of power efficiently with a flat voltage profile. Proper type of compensation should be provided in proper quantity at appropriate places to achieve the desired Voltage Control Method.