Remote protection of three phase distribution transformers

Abstract: It is desirable to provide remote digital protection of distribution transformers. A protection system is disclosed which is able to measure parameters of a supply to a distribution cable (10) to a distribution transformer to provide time related values for the positive sequence current, voltage and phase angle. Time related values for the susceptance of the distribution cable (10) and load connected thereto can then be calculated, and monitored to detect increases in negative susceptance. The triggering of a circuit breaker (19) is then initiated to isolate the distributor cable (10) if the increase exceeds a predetermined thershold increase.

Description: The present invention relates to the remote protection of three phase electricity supply distribution transformers. In a typical supply network, electricity supply is fed from a primary sub station over a distributor cable to several local sub stations at which the supply is transformed by distribution transformers from a relatively high voltage on the distributor cable to the lower voltage at which it is supplied to the domestic consumer. Typically the distributor cable operates at 11 kV in the United Kingdom and the distribution transformers convert this to 415/240V for direct use by customers. It is a required practice that suitable protection is provided for the distribution transformers at these local sub stations to ensure that the transformer is de-energised in the event of a fault arising. Hitherto, this has been done principally by providing local protection and disconnection devices at the distribution transformer using over current devices, e.g. inverse time relays and current breakers or high voltage switch fuses. At the primary sub station it is has been normal to provide only circuit breaker protection to de-energise the entire distributor cable in the event of substantial and sustained over current in the cable. This circuit breaker protection at the primary sub station is quite inadequate to provide protection of remote distribution transformers since the fault current arising from a distribution transformer fault might be inadequate to trip the main circuit breaker at the primary sub station. Nevertheless, it has been proposed to provide more sensitive fault detection devices at the primary sub station with a view to reducing the level of fault protection which must be installed at the local sub station. However, hitherto protection devices fitted at primary sub stations have been insufficiently sensitive to provide adequate protection of distribution transformers located at remote sub stations. Reference should now be made to the following three articles by J. T. Hampson which appeared in Distribution Developments: "Digital Protection" in the issue of June 1983, pages 6 to 8; "New Thinking on HV Radial Protection", in the issue of September 1983, pages 14 to 16; and "Transformer Protection and Control using Digital Techniques", in the issue of December 1983, pages 11 to 13. These articles discuss and disclose a possible solution to the provision of adequate remote distribution transformer protection by a device located at a primary sub station. The articles propose the use of digital sampling of voltage and current on all three phases of the distributor cable at the primary sub station, digital filtering of these samples by Fourier analysis techniques to eliminate harmonic content, and then monitoring the filtered values for relatively sudden increments which might be indicative of a fault. Both Positive Sequence Protection and Negative Sequence Protection is disclosed in the second of the two articles. For the Positive Sequence Protection it is proposed to derive values for the circuit admittance from the filtered values for positive sequence voltage and current, and to monitor the circuit admittance for changes which might be indicative of a fault. It is also suggested that it should be possible to achieve increased sensitivity to incremental admittance changes involving large lagging power factors. It is proposed that a Microprocessor Protection Relay is programmed to take account of power factor by relating it to sensitivity so that sensitivity is in effect mapped against phase angle. For Negative Sequence Protection, the article proposes an "Incremental Voltage-Restraint Over Current Characteristic" for the purpose of providing sufficient sensitivity to negative sequence current caused by imbalance faults on the load side of the primary sub station. If effect, the setting at which a detected negative sequence current increment is considered to be indicative of a distributor fault is increased in accordance with the simultaneously detected level of negative sequence voltage increment. The higher the detected negative sequence voltage increment, the higher must be the detected negative sequence current increment to be considered indicative of a fault. The above mentioned second article finishes by identifying various problems with the proposals set out in the article, particularly problems arising when a heavily loaded distributor circuit is first energised. The proposals outlined in the article could give rise to false operation of the circuit breaker on energising a circuit -which is in fact healthy. The disclosed device is also excessively sensitive to any substantial load switching on the distributor cable which might cause false operation of the circuit breaker. In particular, the disclosed device can be sensitive to the magnetising inrush current on first energising a distribution transformer. The present invention is particularly concerned with important developments of the digital protection proposal outlined in the above three articles which provide substantial improvement in performance. According to the present invention, a method of remotely protecting three phase electricity supply distribution transformers includes the steps of measuring parameters of the supply in a distribution cable to the transformers to provide time related values for the positive sequence current and voltage and phase angle, calculating therefrom time related values for the susceptance of the distributor cable and load connected thereto, monitoring said time related susceptance values to detect increases in negative susceptance, and triggering a circuit breaker to isolate the supply cable if said increase exceeds a predetermined threshold increase. By monitoring the susceptance of the distributor cable and connected load, the positive sequence monitoring at the primary sub station is rendered relatively insenstive to changes in positive sequence current arising from the energising of substantial new load. Fault free load on the great majority of distributors can be expected to have a power factor at or near zero degrees. The connection of fault free load to an energised distributor cable should not give rise to a significant change in the detected susceptance of the cable and load. On the other hand, fault current flowing in the distributor cable owing to a fault in a distribution transformer is almost invariably associated with a substantial lagging power factor so that a sudden increase in positive sequence current resulting from a fault will show a substantial increase in the detected negative susceptance. Conveniently, the time related susceptance values are calculated using the measured values for positive sequence phase angle biased by a predetermined compensation angle selected to produce zero monitored susceptance increase for normal fault free increases in load current. A typical bias angle may be 15°. Normally, in the above described method of protecting, operation of the circuit breaker is delayed following initiating by a time dependent on the magnitude of a detected increase in negative sequence current. Further, the circuit breaker may be delayed following initiation by a time dependent on the magnitude of the detected increase in negative susceptance. In a preferred example, said monitoring step comprises sampling selected parameters of the supply to the distributor cable to provide, for each of successive sampling periods, values for selected functions of said parameter including the negative and positive sequence currents, storing said values from successive sampling periods, and comparing said values for the latest sampling period with stored values of corresponding functions from a previous sampling period to detect increases in said values. Alternatively, where only an increase in the negative susceptance value is being detected, the values of negative susceptance from successive sampling periods are stored and the value for the latest sampling period compared with stored values from previous sampling periods to detect increases. Conveniently, a sampling period constitutes one cycle of the supply waveform and the instantaneous voltage and current of each phase are sampled at a sampling rate nF, where F is the supply frequency and n is an integer greater than 1, the values for said selected functions in each successive sampling period being determined by digitally filtering successive sets of n samples. The present invention also envisages apparatus for remotely protecting three phase electricity supply distribution transformers, comprising means for monitoring parameters of the supply on a distributor cable to the transformers; control means responsive to the monitored parameters to detect an increase in at least one selected function of said parameters which can be indicative of a fault current flowing in the distributor cable, to analyse any such increase to determine the likely existence and magnitude of any such fault current, and to generate a trip signal in accordance with said analysis; and circuit breaker means responsive to said trip signal to isolate the supply cable; wherein said control means is operative to provide from the monitored parameters time related values for the positive sequence current and voltage and phase angle, to calculate therefrom time related values for the susceptance of the distributor cable and load connected thereto, to detect increases in the function, negative susceptance, and to analyse this increase by initiating generation of the trip signal if said detected increase exceeds a predetermined threshold. Conveniently, in the above described apparatus, said control means may comprise digital computer means and said means for monitoring may comprise sampling and digitising means controlled by said computer means repeatedly to sample parameters of the supply and to digitise said samples for reading by the computer means. Then the computer means may be arranged and programmed to read said digitised parameter samples, to calculate therefrom a value for the or each said selected function in each of successive sampling periods, to store said successively calculated values, to compare the latest calculated value from the most recent sampling period with a stored value from a previous period to detect an increase in the value for the or each said function, to perform said analysis of any such increase or increases and to generate said trip signal accordingly. Preferably, the sampling and digitising means is controlled to sample the instantaneous voltage and current in each of the phases of the supply and provide digitised samples of each of these parameters at a sampling rate nF, where F is the supply frequency and n is an integer greater than 1, and wherein the computer means is programmed to calculate a value for the or each said function in each successive cycle of the supply waveform by steps including digitally filtering successive sets of n samples of each parameter to eliminate the harmonic content of the waveform. The digital filtering step may comprise Fourier analysis of the set of n samples to derive sine and cosine terms (A and B) for each parameter such that the amplitude V and phase ø of the respective parameter are represented: ø = tan⁻¹(A/B) V = k A² + B² , where k is a constant. Very conveniently then, the computer means may be programmed to store at least the most recent n digitised samples of each parameter for use in performing said digital filtering step, and is further programmed to effect a selected phase shift of the derived sine and cosine terms of one parameter relative to the terms of another parameter by performing said Fourier analysis on different time rotated sets of n samples for the respective parameters from the stored samples. Examples of the present invention will now be described with reference to the accompanying drawings in which: Figure 1 is a block schematic diagram of microprocessor controlled apparatus for providing protection of an electricity supply distributor cable; and Figures 2 to 6 are flow charts illustrating the computer programme such is employed in the microprocessor of the apparatus of Figure 1. As shown in Figure 1, the three phases of a distributor cable 10 are fed from a primary sub station 11 via a circuit breaker 12. A sampler and digitiser unit 13 is controlled by a microprocessor unit 14 to sample at a predetermined sampling rate the instantaneous current and voltage on each of the three phases, as sensed by respective current transformers 15 and voltage transformer 16. The sampled instantaneous values are digitised in the unit 13 for supply on the data bus 17 to the microprocessor 14 for storage in memory 18. The microprocessor unit 14 is programmed to analyse the stored instantaneous voltage and current readings in accordance with algorithms which will be described in more detail later, so as to detect current and voltage conditions in the three phases of the distributor cable indicative of a fault condition arising on tire load side of the circuit breaker. On detection of a fault condition, the microprocessor unit 14 is then further programmed to initiate a triggering procedure resulting in signalling a trip output relay 19 to operate the circuit breaker 12 to isolate the distributor cable 10 from the primary sub station 11. The microprocessor unit 14 is controlled in accordance with a programme which may be held in part of the memory 18. The programme is divided into various tasks known as SAMPLE, FILTER, EVAL and PROTECTION. Figure 2 is a flow chart of the SAMPLE task. The task is called by means of an interrupt signal in the computer every 1.66 mS. Each time the task is called, the computer controls the sampler and digitiser 13 to obtain fresh instantaneous samples of the current and voltage on each of the three phases and to digitise these samples. The microprocessor also then reads the digitised samples presented on the data bus 17 and stores these in locations of the memory 18. The microprocessor is then arranged to call the FILTER task following every twelth execution of the SAMPLE task. It can be seen therefore that the FILTER task is called every 20 mS, i.e. once per cycle of a 50 Hz supply waveform. On the other hand the voltage and current of the supply waveform are sampled 12 times per cycle. Figure 3 is a flow chart of the FILTER task in the microprocessor programme. The filter task performs a Fourier analysis of a set of twelve successive samples for each of the measured parameters of voltage and current for each phase, so as to provide Fourier sine and cosine (A and B) terms for the fundamental frequency of each of these parameters. This Fourier analysis effectively filters out the higher harmonics which may be present in the voltage and current waveforms. Digital Fourier analysis techniques are well known for this purpose and, in the present case, the A and B terms of the 50 Hz; fundamental for the voltage and current parameters are derived from the equations: where S₀ to S₁₁ are the digitised sample values for each of the set of twelve samples used for the Fourier analysis of a particular parameter. The peak amplitude of the parameter is then represented by: (A² + B²) . Similarly the phase angle of the parameter is represented by: Tan⁻¹(A/B). The microprocessor 14 is arranged to maintain in the memory 18 the most recent 48 samples for each of the monitored parameters of the three phase supply, thereby providing samples over the last four cycles of the supply waveform. When performing the Fourier analysis, or digital filtering, of the sets of twelve samples for each parameter, a phase shift between the various parameters is introduced by performing the courier analysis on different time shifted sets of twelwe successive samples. For example, if the non phase-shifted red phase current I R is determined using red phase current samples S₀ to S₁₁, the yellow phase current with 120° phase shift is determined using yellow phase current samples S₄ through S₁₁ to S₃. In order to calculate the positive and negative sequence components of current for the three phase supply, the computer is programmed to determine the Fourier A and B components of each of the following parameters: I R - red phase current (no shift) I Y120 and I Y240 - yellow phase current with 120° and 240° shifts I B120 and I B240 - blue phase current with 120° and 240° shifts. When determining voltage parameters of the three phases, a 30° phase shift is required to adjust for the phase to phase voltage transformer connections used in monitoring the voltage on the three phases of the cable. Thus for determining positive and negative sequence components of voltage, the Fourier A and B terms are calculated of each of the following voltage parameters: V RY330 - red-yellow voltage shifted by 330° (or -30°) V YB90 and V YB210 - yellow-blue voltage shifted by (120° - 30°) and by (240° - 30°) V BR90 and V BR210 - blue-red voltage shifted by (120° - 30°) and by 240° - 30°). Having thus determined the A and B terms of each of the above parameters by the digital filtering or Fourier analysis technique described above, the A and B terms of the positive and negative sequence voltage and current values are then separately calculated from the following formalae in which the I and V terms indicated are taken to represent firstly the Fourier A term of the respective current or voltage parameter and then the Fourier B term of the respective parameter: I pos = (I R + I Y120 + I B240 )/3 V pos = (V RY330 + V YB90 + V BR210 )/3 I neg = (I R + I Y240 + I B120 )/3 V neg = (V RY330 + V YB210 + V BR90 )/3. In addition, the microprocessor is programmed to calculate the D.C. current in each phase by simply determining the sum of all twelve samples. Once the programme has completed the FILTER task as outlined above, the EVAL task is activated. A flow chart of the EVAL task is illustrated in Figure 4 of the accompanying drawings. The first step in the EVAL task is to evaluate the phase of the positive sequence current and voltage from the A and B terms derived by the FILTER task employing the formulae: ø = Tan⁻¹(A/B). Next, the computer evaluates the amplitude of the positive and negative sequence current and voltage from the A and B terms for these parameters and normalises the evaluated amplitudes to a per-unit value equal to 1024 in binary. The resulting evaluated phases of the positive sequence current and voltage will be referred to hereafter as ø I and ø V , and the most recently evaluated normalised amplitudes of the positive and negative sequence current and voltage as IOP, VOP, ION, VON. The EVAL task finally evaluates the amplitude of any detected D.C. current in each phase, again normalising the value to a per-unit of 1024. On completing the EVAL task, the computer is programmed to start the PROTECTION task. The PROTECTION task in the programme is illustrated in the flow chart on Figures 5 and 6. The first function of the PROTECTION task is to check for any excessive increments in the detected D.C. current on any phase. This is done by the computer by checking the latest values for D.C. current as calculated in the immediately preceding EVAL task with corresponding values calculated on previous cells of the EVAL task following previous cycles of the supply waveform. Normally, the incremental detection is performed by comparing the latest calculated value with that calculated two cycles previously. If a sudden increment in D.C. current in excess of a threshold is detected in any phase of the supply, the programme is arranged to skip all subsequent testing functions of the PROTECTION task, either until the D.C. current has returned to its previous level, or else until a certain time has elapsed following the sudden increase. The time delaying feature is embodied in the programme by use of a software function which mimics the operation of an induction disk relay, used in electricity distribution systems for providing a time delay between detection of a fault current and opening of a circuit breaker. The time delay is typically dependent on the detected size of the fault current (the relaying quanitity) and the setting designed to ensure that the operation of the circuit breaker is properly graded with the operation of other circuit breakers and fuses in the distribution circuit. Accordingly the programme in the present example responds to detection of an excessive D.C. current increment in a particular phase by starting a counting process in a particular location of the memory and setting a flag to indicate that the respective "D.C. relay" is operating. The flag remains set either until the D.C. relay is halted when the D.C. current value reverts to the value before the increment, or else when the D.C. relay times out following a time delay determined inter alia by the size of the detected increment. The programme is arranged to check to see if any of the D.C. relays are operating and not yet timed out and if so to skip all the remaining functions of the PROTECTION task as shown in the flow chart. However, if none of the D.C. relays are operating, or else if a recently operating D.C. relay has now timed out, the PROTECTION function continues by performing the first check on the calculated values for positive and sequence voltage and current. This first check is to look for a sudden increment in the positive sequence current. Thus, the latest calculated value for the positive sequence current (IOP) is compared with that calculated two cycles previously (I2P) to see if the difference between the two is greater than a preset threshold. If the difference is greater than the threshold, then the programme sets an I pos flag to indicate that a positive sequence current increment has been detected. The next function of the PROTECTION task is to monitor the negative sequence current. For this purpose a bias value is first calculated comprising: (IOP - I2P) 8 + 2 (VON - V2N) Then, the latest calculated value for negative sequence current is compared with that calculated two cycles previously and if the difference is greater than a preset threshold plus the previously calculated bias value, a NPS flag is set to indicate that a likely negative phase sequence fault has been detected. It can be seen that the above referred bias includes a proportion of the detected increment in positive sequence current so that the NPS flag is not set unless the detected increase in negative sequence current exceeds the preset threshold plus this proportion of any simultaneous increase in positive sequence current. At the same time, the bias includes a factor times any simultaneous detected increase in negative sequence voltage. The purpose of these bias components will be described again in more detail later. The next function in the PROTECTION task is to determine whether there is an excessive increase in the negative susceptance of the protected cable and load. For this purpose the programme first checks the calculated values for positive sequence voltage and current phase angle to ensure that these calculated values are valid. When the EVAL task is calculating the phases of the positive sequence voltage and current, it is unable to resolve the angle if the input quantity is too small, in which case the most significant bit of the word containing the phase angle is set. In the PROTECTION task, the programme first checks the most significant bits of the phase angle values to ensure none are set so that all the indicated values are to be considered valid. The programme then subtracts the phase of the positive sequence voltage from that of the positive sequence current to determine the phase angle ø and then calculates the positive sequence susceptance (SOP) from the formula: SOP = IOP VOP x sin (ø + Q C ). Q C is a compensation angle which represents the worst case load angle along which increments in normal fault free load should occur and for which no resultant sensitivity to susceptance increment is needed. A typical value for Q C is 15° so that a load at a lagging angle of 15° would then yield a calculated susceptance (SOP) of zero. The programme makes any calculated positive values of SOP equal to zero and then negates any remaining values of SOP. In the event that one or other of the calculated phase angles is considered invalid, the programme arranges for the calculated susceptance value SOP to be set to zero. The most recent calculated susceptance value is then compared with that calculated two cycles previously (SOP - S2P) to see if the difference exceeds a predetermined threshold. It can be seen therefore that the difference SOP - S2P for a lagging fault condition resulting in an increase in negative susceptance, yields a positive value for comparison with the threshold. If the detected increase in negative susceptance is above the threshold, an S flag is set indicative of a likely positive sequence fault condition. The remaining functions of the PROTECTION task of the programme analyse the results of the various tests on changes in the positive and negative sequence current and negative susceptance to determine whether there is in fact a fault condition on the distributor cable and the estimated magnitude of the fault. If the I pos flag is set and also at least one of the NPS or S flags is set, a relaying quantity Q is determined according to the formula: Q = 5 4 (SOP - S2P) + 3 4 (ION - I2N) The relaying quantity Q so calculated is then used to set a time delaying relay function in the programme which again operates by imitating the operation of an induction disk relay. The higher is time calculated value of Q the shorter is the delay time produced by the relay before a signal is generated by the computer to operate the trip output relay 19 which in turn operates the circuit breaker 12. If the I pos flag is not set, or else if neither of tire NPS or S flags are set, then the relaying quantity Q is set at 0, so that the procedure for operating the circuit breaker 12 is not initiated. Whilst the relay function in the programme is operating, i.e. the tripping of the circuit breaker has been initiated but the delay time has not yet timed out, the programme ensures that the previously used values S2P, I2P, I2N and V2N are frozen and not updated. This ensures that the next time the PROTECTION task is called, following the next cycle of the mains supply waveform, the latest measured and calculated values for S0P, I0P, I0N, V0N, are still compared with the previous reference values which are now the values from three cycles previously. This freeze condition continues until the programme determines that the time delaying relay is no longer operating. This freezing operation ensures that the latest condition of the supply continues to be checked against that immediately preceding the fault condition. If the supply returns to within the threshold values immediately preceding the fault condition, the checks in the PROTECTION task will result in the various flags being reset so that the relaying quantity Q is set to zero, thereby inhibiting further operation of the delaying relay and causing it to reset before it has timed out. In this way, a fault condition detected but not :maintained for the delay time required to allow the delaying relay to time out, does not result in operation of the circuit breaker 12. If the delaying relay is found not to be operating, i.e. Q has been set at zero, then the programme ensures that the value for S2P, I2P, I2N and V2N are updated with the values from the immediately preceding cycle S1P, I1P, I1N and V1N. Then the next time the PROTECTION task is called, following the next cycle of the supply waveform, the latest determined values for these functions will be compared once again with those from two cycles previously. In all cases, whether the delaying relay is operating or not, the values S1P, I1P, I1N and V1N are updated before completion of the PROTECTION task to be set to the recently calculated values S0P, I0P, I0N and V0N. The final check performed by the PROTECTION task is to determine whether the delaying relay, if set operating, has yet timed out. If it has, the computer provides a control signal to operate the trip output relay 19 so that the circuit breaker 12 is operated. The determination of the relaying quantity Q in the above described part of the PROTECTION task is arranged to provide an evaluation of the magnitude of a fault condition which has been detected so as to ensure proper grading of the operating of the circuit breaker 12 with other circuit breaking elements which may be provided in the distributor circuit. Accordingly the factors employed in the above example as multipliers for the negative susceptance increment and the negative sequence current increment may be determined empirically to provide the required grading for the protection apparatus for various types of fault situation. When the protection apparatus is programmed as described above, it is able to distinguish with a high degree of reliability between actual faults occuring on the distributor circuit and other parameter changes which are not normally indicative of a true fault. By use of incremental techniques, the settings at which various possible faults are indicated can be for actual fault currents which are significantly below the normal load current in the distributor cable. By biasing the setting for negative sequence current increments with a proportion of any simultaneous positive sequence current increment, the protection system can be rendered relatively insensitive to the substantial change in negative sequence current which can occur temporarily during the magnetising inrush current when energising a distribution transformer. By also biasing the setting for negative sequence current increments in accordance with simultaneously detected negative sequence voltage increments, the system can be made relatively insensitive to unbalanced disturbances on the source side of the protection apparatus. By detecting increases in negative susceptance derived from the positive sequence current and voltage, true positive sequence faults can be detected at relatively low current levels compared to the normal load current.

Claims: A method of remotely protecting three phase electricity supply distribution transformers including the steps of measuring parameters of the supply on a distributor cable to the transformers to provide time related values for the positive sequence current and voltage and phase angle, calculating therefrom time related values for the susceptance of the distributor cable and load connected thereto, monitoring said time related susceptance values to detect increases in negative susceptance, and initiating the triggering of a circuit breaker to isolate the supply cable if said increase exceeds a predetermined threshold increase. A method as claimed in Claim 1 wherein the time related susceptance values are calculated using the measured values for positive sequence phase angle biased by a predetermined compensation angle selected to produce zero monitored susceptance increase for normal fault-free increases in load current. A method as claimed in any preceding claim, wherein operation of the circuit breaker is delayed following initiation by a time dependent on the magnitude of a detected increase in negative sequence current. A method as claimed in Claim 1 or Claim 2, wherein operation of the circuit breaker is delayed following initiation by a time dependent on the magnitude of the detected increase in negative susceptance. A method as claimed in any preceding claim, wherein said monitoring step comprises sampling selected parameters of the supply to the distributor cable to provide, for each of successive sampling periods, values for selected functions of said parameters including the negative and positive sequence currents, storing said values from successive sampling periods, and comparing said values for the latest sampling period with stored values of corresponding functions from a previous sampling period to detect increases in said values. A method as claimed in Claim 5 wherein a sampling period constitutes one cycle of the supply waveform and the instantaneous voltage and current of each phase are sampled at a sampling rate nF where F is the supply frequency and n is an integer greater than one, the values for said selected functions in each successive sampling period being determined by digitally filtering successive sets of n samples. Apparatus for remotely protecting three phase electricity supply distribution transformers, comprising means (13) for monitoring parameters of the supply in a distributor cable (10) to the transformers; control means (14,18) responsive to the monitored parameters to detect an increase in at least one selected function of said parameters which can be indicative of a fault current flowing in the distributor cable, to analyse any such increase to determine the likely existence and magnitude of any such fault current, and to generate a trip signal in accordance with said analysis; and circuit breaker means (19) responsive to said trip signal to isolate the supply cable; wherein said control means (14,18) is operative to provide from the monitored parameters time related values for the positive sequence current and voltage and phase angle, to calculate therefrom time related values for the susceptance of the distributor cable (10) and load connected thereto, to detect increases in the function, negative susceptance, and to analyse this increase by initiating generation of the trip signal if said detected increase exceeds a predetermined threshold. Apparatus as claimed in Claim 7 wherein said control means (14,18) comprises digital computer means (14,18) and said means (13) for monitoring comprises sampling and digitising means (13) controlled by said computer means (14,18) repeatedly to sample parameters of the supply and to digitise said samples for reading by the computer means (14,18). Apparatus as claimed in Claim 8 wherein the computer means (14,18) is arranged and programmed to read said digitised parameter samples, to calculate therefrom a value for the or each said selected function in each of successive sampling periods, to store said successively calculated values, to compare the latest calculated value from the most recent sampling period with a stored value from a previous period to detect an increase in the value for the or each said function, to perform said analysis of any such increase or increases and to generate said trip signal accordingly. Apparatus as claimed in Claim 9 wherein the sampling and digitising means (13) is controlled to sample the instantaneous voltage and current in each of the phases of the supply and provide digitised samples of each of the parameters at a sampling rate nF where F is the supply frequency and n is an integer greater than one, and wherein the computer means is programmed to calculate a value for the or each said function in each successive cycle of the supply waveform by steps including digitally filtering successive sets of n samples of each parameter to eliminate the harmonic content of the waveform. Apparatus as claimed in Claim 10 wherein the digital filtering step comprises Fourier analysis of the set of n samples to derive sine and cosine terms (A and B) for each parameter such that the amplitude V and phase ø of the respective parameter are represented: ø = tan⁻¹ (A/B) V = k A² + B² , where k is a constant Apparatus as claimed in Claim 11 wherein the computer means (14,18) is programmed to store at least the most recent n digitised samples of each parameter for use in performing said digital filtering step, and is further programmed to effect a selected phase shift of the derived sine and cosine terms of one parameter relative to the terms of another parameter by performing said Fourier analysis on different time rotated sets of n samples for the respective parameters from the stored samples.

Inventors: HAMPSON JOHN THOMAS, HAMPSON, JOHN THOMAS
Applicants: ELECTRICITY ASS SERVICES LTD, ELECTRICITY ASSOCIATION SERVICES LIMITED
Application year: 1987
Main classification: H02H3
IPC codes: H02H3, H02H1