MXPA98005059A - Robust meter of company electr - Google Patents

Abstract

The present invention includes an operable electric utility meter for measuring energy consumption. The method detects and compensates for one or more wiring errors that alternate the energy consumption measurement of the electric utility meter. The method includes the steps of: obtaining measured phase angle data for a plurality of phases in a polyphase electrical system, periodically performing one or more diagnostic tests using the measured phase angle data to determine whether a wiring error is present, automatically adjusting the operation of the utility company's meter to effect a compensation for the wiring error, the compensation increases the accuracy in the energy consumption measurement of the electricity company's meter. The meter is operable to detect and compensate for wiring errors that include polarity errors and cross-phase errors. According to another embodiment of the present invention, the meter is operable to automatically determine the type of service to which it is connected.

Description

ROBUST METER OF CCMPAÑTA PTT.raT Tna FIELD Dg LA. NVENCON The present invention relates generally to electricity utility meters, and in particular to utility or utility meters for use in multi-phase or multi-phase power configurations.

ANI 'CKÜE TES DE LA INVENCIÓN Service providers of electric companies, or simply electric companies, monitor the use of energy by consumers through electricity company meters. The meters of the electric companies follow the amount of energy conceived, typically measured in kilo ats -hours ("kwh"), in the installation of each user. Utilities use consumer information primarily for manufacturing, but also as an allocation resource and other purposes. Power companies generate polyphase power, and typically three-phase power. The polyphase electric energy is electric power of alternating current that is supplied in a plurality of REF: 27724 power supply lines. The voltage waveform of each of the power supply lines has a unique phase angle. Although only a single phase of polyphase electrical power is typically provided for single-family homes, true multi-phase electric power is generally provided to larger facilities such as commercial and industrial structures. Historically, electric utility meters use an inductive spin disk to measure energy consumption. In such meters, the speed at which the rotating disk rotates varies proportionally with the amount of electrical energy consumed. The rotating disc drives mechanical contras which, in turn, provide information about the use of accumulated energy. A recent development in electrical utility meters is electronic meters. Electronic meters replace the previous inductive rotating disc meter design. Electronic meters have several advantages, including the advantage of providing features beyond a simple or linear energy consumption measurement. Electronic meters, for example, can track energy demand, energy factor and energy measurements per phase. In addition, electronic meters can alter the method by which they calculate energy consumption in order to adapt to different wiring in the construction and energy configurations, thereby increasing the versatility of the meters. Electronic meters are also capable of very sophisticated diagnostics. For example, U.S. Patent No. 5,469,049 to Briese et al. , describes a diagnostic toolbox that is built into the meter. The diagnostic toolbox in Briese et al.'s device measures the voltage per phase and the current magnitude and phase angles, and then compares the measured values with the expected values to determine if a wiring error is present. A wiring error is an error in which in the meter itself or in the interconnection between the meter and the electrical system to which it is connected. Wiring errors typically cause a meter to make substantially inaccurate energy measurements. As a result, wiring errors can cause substantial losses of the revenue ratio with respect to utilities because the meter does not accurately record the actual amount of energy that is consumed. A drawback in the meter described in the Briese et al. Patent is that it shows identified errors, but requires service to correct the errors. Therefore, although the error can be suppressed and displayed, the utility will continue to lose revenue until a service person is sent to correct the error. Another drawback with the Briese et al., is the way in which it must be preconfigured for the wiring configuration and the voltage level or Type of Service, to which it will be connected. Preconfiguration requirements are undesirable. For example, the preconfiguration of the meter during its manufacture introduces undesired complexity in the inventory and supply systems. Likewise, it requires a technician to provide such input to the meter during installation which undesirably increases the associated complexity when the meters are installed.

BRIEF DESCRIPTION OF THE INVENTION The present invention solves these and other drawbacks of the prior art by automatically identifying the type of service to which the meter is connected to facilitate diagnosis and to adjust the operation of the meter to compensate for any wiring errors detected during diagnosis.

The present invention includes an operable electric utility meter for measuring the power consumption in a polyphase electrical system. The method detects and compensates for one or more wiring errors that alter the energy consumption measurement of the utility company's meter. The method includes the steps of: obtaining phase angle data measured for a plurality of phases in a polyphase electrical system; Perform one or more diagnostic tests periodically using the measured phase angle data to determine if a wiring error is present, and automatically adjust the operation of the utility company's meter to carry out a compensation for the wiring error, such compensation increases the measurement accuracy of power consumption of the electrical installation meter. The meter is operable to detect and compensate for wiring errors that include polarity errors and cross-phase errors. According to another method of the present invention, the meter is operable to automatically determine the type of service to which it is connected. These, as well as other features and advantages of the present invention will become more readily apparent to those usually familiar with the art, with reference to the following detailed description and accompanying drawings.

BRIEF DESCRIPTION OF THE DRAWINGS Figure 1 shows an overview of a wired electric utility meter for measuring a three-phase electric power service; the figure shows a phasor diagram that illustrates the relationship between the three voltages and current phases in the wired meter as shown in figure 1; Figure 2 shows an overview of a wired electric utility meter for measuring three-phase electric power in a manner that includes a voltage polarity error in which a voltage phase is 180 ° out of phase; Figure 2a shows a phasor diagram illustrating the relationship between the three voltage phases and the current phases measured by the wired meter as shown in Figure 2, - Figure 3 shows an overview of an electric utility meter wiring to measure three-phase electrical energy in a way that includes a cross-phase error in which two current phases are crossed; Figure 3a shows a phasor diagram illustrating the relationship between the three voltage phases and the current phases measured by the wired meter as shown in Figure 3; Figure 4 shows a block diagram of an electric company meter according to the present invention; Figure 5 shows a flow chart of the general operations operations for controller of an electric utility meter, according to the present invention; Figure 6 shows a more detailed flow diagram of the operations performed by a controller in an exemplary embodiment of the present invention; Figures 7, 7a, 8 and 9 show detailed flow diagrams of the operations performed by a controller to detect a plurality of wiring errors and make compensations for the wiring errors detected; and Figure 10 shows a table of expected values corresponding to a plurality of service types.

DESCRIPTION rrcrrat.t.ApA Figure 1 shows a summary overview of a wired electric utility meter for measuring a three-phase electric power service. A meter 10 is shown, and a set of polyphase power lines including a phase 12 energy line A, a phase B energy line 14 and a phase C energy line 16., and a neutral line 18. The meter 10 includes sensor circuits comprising a phase A current sensor 20, a phase B current sensor 22, a phase C current sensor 24, a phase voltage sensor A, a voltage sensor 28 of phase B and a phase voltage sensor 30. The meter 10 includes a measurement circuit, not shown (see FIG. 4), which generates energy consumption measurements and other information of the currents and voltages detected by the sensors. , 28 and 30 of voltage and current sensors 20, 22 and 24. The phase current sensor 20 is connected to a first transformer 32, which in turn is advantageously placed to detect current in the line of energy of phase A. Similarly, the current sensor 22 of phase B is connected to a second transformer 34 which in turn is advantageously placed to detect current in the line 14 of phase energy B. The phase current sensor C is connected to a third transformer 36 placed in an analogous manner. The phase voltage sensor A 26 is connected between the line 12 of phase A energy and the line 18 neutral. The phase voltage sensor B is connected between the line 14 of phase B energy and the line 18 neutral. The phase voltage sensor C is connected between the phase power line 16 and the neutral line 18. Line 12 of phase A energy, line 14 of phase B energy and phase line of energy C are part of a four-wire 120-volt Y-type service, which is well known in the technique. The polyphase electric power is provided to the users in a plurality of configurations, known as service types. A type of service is typically defined by the nominal voltage level and the wiring configuration. A cabling configuration is further defined by the number of cables (three cables or four cables) and the wiring relationship between the phases (in the form of Y or delta). For example, a four-wire 120-volt Y-type service has a nominal voltage level of 120 volts and a four-wire Y-wiring configuration. The most commonly used types of service are standardized and well known by those usually familiar with the technique. Different types of standard watt-hour meters, known as metering forms, are used to measure the energy consumption for the various types of service. The exemplary meter 10 of Figure 1 has a meter form 9S. As is well known in the art, in the form of the meter that is suitable for use in a particular user installation depends on numbers or factors including: the type of service, the maximum expected current level; the necessary precision; the cost; and if the wiring configuration has a common neutral. Commonly used measurement forms include those referred to as 5S, 45S, 6S, 36S, 9S, 16S, 12S and 25S measurement forms, and each is capable of measuring a plurality of service types. The use of a 9S measurement form for the meter 10 is provided in an exemplary manner only and the implementation of the present invention is not limited in any way to a particular measurement form. The figure shows a phasor diagram illustrating the relationship between the three voltages and the current phases detected by the sensor circuits of the meter 10, as it is wired in Figure 1. Generally, in a Y-shaped wiring configuration of Four wires, the three voltage phases will typically be separated by a phase angle of approximately 120 °, as will the three current phases. Each phase current and its corresponding phase voltage are typically separated by a phase angle of from 0 to 90 °, for example such as 30 °, as shown in FIG. The phase angle varies in - li basis to the type of load that is attached to the electrical system that is being measured. For purposes of clarity with respect to some of the advantages of the present invention, Figures 2 and 3 illustrate two situations in which a wiring error can cause a loss of revenue for an electric utility. Figure 2 shows a general view of an electrical company meter wired in a manner that includes a wiring error known as voltage polarity error. A voltage polarity error is an error in which the measurements of a voltage phase are 180 ° out of phase. For purposes of clarity, the components of Figure 2 will have the same reference numbers as similar components in Figure 1. As shown in Figure 2, the connection between the phase 16 power line C and the voltage sensor 30 of phase C have been juxtaposed with the connection between the neutral line 18 and the phase voltage sensor 30. The result of this juxtaposition is that the phase voltage C detected by the sensor circuits of the meter 10 will be detected as 180 ° out of phase, as shown in figure 2a. Because the phase C voltage is 180 ° out of phase, the phase C energy measurements, VC * IC, will produce negative values. The introduction of a measurement of negative energy consumption greatly reduces the measurement of overall energy consumption, resulting in losses in revenue for the utility. In accordance with the present invention, as discussed in more detail below in relation to Figures 4 and 7, the measurement circuits of the meter 10 identify, and consequently compensate for a voltage polarity error illustrated in Figures 2 and 2a . As a result, the measurement of compensated energy consumption does not have a negative component and therefore is more accurate. Figure 3 shows a general view of a wired electric utility meter in a manner that includes a wiring error known as a cross phase error. A cross phase error is an error in which measurements of two current phases are exchanged, often due to cross wiring. For purposes of clarity, the components of Figure 3 will have the same reference numbers as similar components in Figure 1. As shown in Figure 3, the connection between the first transformer 32 and the phase current sensor 20 is They have juxtaposed with the connection between the second transformer 34 and the phase B current sensor 22. The result of this juxtaposition is that the detection circuit will process the current from phase A as the current from phase B and vice versa. Figure 3a shows a phasor diagram illustrating the relationship between the three voltage phases and the current phases measured by the detection circuit with the cross wiring error illustrated in Figure 3. The cross phase also results in energy measurements substantially inaccurate that cause losses of income to the electricity company. In accordance with the present invention, as discussed in more detail below in relation to Figures 4 and 8, the measuring circuits of the meter 10 identify, and consequently compensate for the cross-phase error illustrated in Figures 3 and 3a. Figure 4 shows a block diagram of an electric company meter according to the present invention. The meter 10 essentially comprises sensor circuits 102 and a measurement circuit 104. The sensor circuits 102 include the phase-current sensor 20, the phase-current sensor B and the phase-current sensor 24, as shown in FIGS. 1, 2 and 3, collectively referred to as FIG. the polyphase current sensor. The sensor circuits 102 further include a phase voltage sensor A 26, a phase voltage sensor B and a phase voltage sensor 30, as shown in FIGS. 1, 2 and 3, collectively referred to as a Polyphase voltage sensor. The measurement circuit 104 further comprises a conversion circuit 106, a processor 108, a non-volatile memory 110, a screen 112 and a communication port 114. The phase current sensor 20 is connected to receive a signal indicative of the current flow through the phase line 12 of energy A (see Figure 1). For this purpose, as shown in FIG. 1, the phase current sensor 20 is connected to the first transformer 32, which is advantageously placed to detect current in the phase line 12 of energy A and produce a signal indicative of the amount of current in it. The phase current sensor A is additionally connected to the measurement circuit 104 through the first multiplexer 116. The phase current sensor 20 may be constituted by a current transformer or any other device known in the art which detects current from the first transformer 32 and produce a signal indicative of the amount of detected current. In alternative modes the current sensor 20 directly measures the current flowing through the line A of phase energy A, as a result, the first transformer 32 is not needed. Direct measurement of the current is made in self-contained meter forms , which are well known, an embedded coil sensor can be suitably used as a current sensor in self-contained meter forms.

The phase current sensor B is connected to receive a signal indicative of the current flowing through the phase energy line 14 (see FIG. 1), in a manner analogous to that described above in connection with the phase A. The phase current sensor B is additionally connected to the measurement circuit 104 through the first multiplexer 116. Likewise, the phase current sensor C is connected to receive a signal indicative of the flowing current through line 16 of phase C energy (see Figure 1). The phase current sensor C is also connected to the measurement circuit 104 through the first multiplexer 116. The phase current sensor B and the phase current sensor C preferably have the same structure as the sensor 20 of the current. phase current A. The phase voltage sensor A 26 is connected directly to the phase A phase power line 12 (see figure 1) to obtain a voltage measurement thereof. For this purpose, the phase voltage sensor A 26 can be suitably constituted of a high resistance voltage divider. The phase voltage sensor A 26 is additionally connected to the measurement circuit 104 through a second multiplexer 118. Likewise, the phase voltage sensor B is connected to obtain a voltage measurement of the power line 14 of phase B, and is additionally connected to provide the voltage measurement to the second multiplexer 118. The phase voltage sensor C has a similar structure and is connected to the phase 16 power line C and the multiplexer 118 in a manner analogous to the phase voltage sensor 26 and the voltage sensor 28 of phase B. The conversion circuit 106 is an operable circuit for receiving polyphase voltage and polyphase current measurement signals, and generating digital data therefrom. The digital data generated includes energy consumption data and data of measured voltage, current amplitude and phase angle. In the exemplary embodiment described herein, the conversion circuit comprises a first, second and third multiplexers, 116, 118 and 120, respectively, and a first, second and third analog to digital converter.

("A / D") 122, 124 and 126, respectively, in a processor 128 of digital signal. The components mentioned before the conversion circuit 106 can suitably be incorporated into a single semiconductor substrate. An example of a suitable conversion circuit is the Power Measurement Integrated Circuit found in the S4 model electric utility meters available from Landis & Gyr Utility Services, Inc.

The controller 108 is operably configured to, and executes programming instructions to receive digital data from the conversion circuit 106, monitor and record power consumption using the digital data, and determine if one or more wiring errors are present using the digital data. Suitably, controller 108 may be a K0 series microcontroller available from NEC. The controller 108 generally includes microprogramming (firmware), or in other words, an integrated memory in which programming instructions are stored. Alternatively, the programming instructions can be stored in a non-volatile memory 110. The third multiplexer 120 and a third A / D converter 126 provide additional capabilities to the meter 10 that are outside the scope of the present invention. In operation, the current sensors 20, 22 and 24 of the phases A, B and C, respectively, detect the phase current A, the phase current B and the phase current C. The phase current sensor 20 provides a phase A current measurement signal to the first multiplexer 116, the phase current sensor B provides a phase B current measurement signal to the first multiplexer 116, and the phase C current sensor 24 provides a signal of current measurement of phase C to the first multiplexer 116. Each current measurement signal typically comprises a signal having a voltage level that is representative of the instantaneous current level in its respective phase. For current transformers designed for use by utility companies, the current measurement signals are of a relatively low amplitude. For example, in the modalities that use the Power Measurement Integrated Circuit from Landis &; Gyr Utility Services, the measurement of the current measurement signals are from 0.0 Vrms to 0.3 Vrms maximum. Of course, other graduation factors can be used in other modalities. The first multiplexer 116, under the control of the controller 108, provides the current measurement signal instantaneously from one of the phase A, phase B or phase C current measurement signals to the first A / D converter 122. The first multiplexer 116 typically provides each phase in rapid succession of cycles, so that each phase is provided to the first A / D converter 122 every third cycle. In accordance with the exemplary embodiment described herein, the first multiplexer 116 provides the current measurement signals at a cycle rate of 3.3 kHz. The first 122 A / D converter receives and samples or digitizes the rapid succession of instantaneous current measurement signals. Subsequently, the first A / D converter 122 provides DSP 128 with a stream of digital current measurement samples, each representing the magnitude of one of the three-phase currents at a particular time. The stream of digital words provided by the first A / D converter 122 is referred to herein as a digital current measurement signal. Contemporaneously, phase voltage sensors A, B, and C, respectively, detect the phase A voltage, the phase B voltage, and the phase C voltage, the voltage sensor 26. of phase A provides a voltage measurement signal from phase A to second multiplexer 118, voltage sensor 28 of phase B provides a phase voltage measurement signal from phase B to second multiplexer 118, and sensor 30 voltage of phase C provides a current measurement signal from phase C to second multiplexer 116. Each voltage measurement signal is typically a signal having a voltage level that is representative of the instantaneous voltage level in its respective phase . In the exemplary embodiment described herein, which utilizes the Power Measurement Integrated Circuit, the voltage sensors are configured to provide voltage measurement signals ranging from 0.0 Vrms to 0.3 Vrms maximum. Of course, other graduation factors can be used in other modalities. The second multiplexer 118 subsequently provides, one at a time, the instantaneous voltage measurement signals from phase A, phase B or phase C to the second converter 124 A / D. For this purpose, the second multiplexer 118 is controlled by the controller 108. The second multiplexer 118 typically provides each phase voltage measurement signal in a rapid succession of cycles, so that each phase is provided to the second converter 124 A / D every third cycle. In any case, the second A / D converter 124 receives and samples or digitizes the rapid succession of instantaneous voltage measurement signals. The second A / D converter 124 then provides a digital voltage measurement sample stream, or simply a digital voltage measurement signal to the DSP 128. The first A / D converter 122 and the second A / D converter 124 provide the signals of digital voltage and current measurement in a predetermined coordinated phase relationship. In accordance with the exemplary embodiment described herein, the second multiplexer 118 provides the voltage measurement signals at the same rate as that used by the first multiplexer 116 to provide the current measurement signals to the first A / D converter 124. In addition, the first multiplexer 116 and the second multiplexer 118 operate in a coordinated manner to provide certain phase current measurement signals at the same time as certain voltage measurement signals of. phase. For example, in a four-wire Y-shaped meter configuration, the first multiplexer 116 provides the phase-current measurement signal x and the second multiplexer 118 provides the phase-voltage measurement signal x at the same time., wherein x rotates between A, B and C. The DSP 128 within the conversion circuit 106 receives the digital current measurement signal and the digital voltage measurement signal determines the power consumption therefrom. For this purpose, the DSP 128 selectively multiplies the voltage measurement samples and the current measurement samples, received from the A / D converters 122 and 124, and then adds them together. For example, in a Y-shaped configuration of four wires, the appropriate calculation of energy is: (1) ENERGY = VAIA + VBIB + VCIC, Where the energy is given in watts. The DSP 128 performs the above calculation in the manner described below. As discussed above, the converters 122 and 124 A / D provide the current and voltage measurement samples for each phase contemporaneously. The DSP 128 multiplies each voltage measurement sample with the current measurement sample received contemporaneously. The resulting product is added to a running total or sum. In other words, if DIG_VX is a sample of a digital voltage measurement signal for a phase x and DIG_IX is a sample of a digital current measurement signal for phase x, then the DSP 128 performs the following calculation: (2) ENERGY = SUM (CAL_VX DIG_VX * CAL_IX DIG_IX) for x =. { A, B, C, A, B, ....}. where CAL_VX and CAL_IX are the calibration constants per phase. The calibration constants per phase are determined empirically during manufacturing and consider the variance in the voltage and operation of the current sensing device. The DSP 128 provides energy measurement data to the controller 108 at regular time intervals, the energy measurement data consisting of the sum of ENERGY for each time interval. Then, the controller 108 accumulates the energy measurement data until a predefined watt-hour threshold unit has been reached. Once a predefined watt-hour unit threshold has been reached, the controller 108 generates a power consumption pulse and then increases the energy consumption counter. Then, the controller 108 repeats the process or, in other words, begins to accumulate energy measurement data until a predetermined watt-hour threshold is again reached. The energy consumption meter is the means by which the user's energy consumption is monitored. For example, as is well known, an electric utility can determine the particular consumption of users for a particular billing cycle by subtracting the energy consumption account value at the beginning of the billing cycle, from the value of the energy consumption meter to the end of the billing cycle. Preferably, the controller 108 provides power consumption counter information in both the non-volatile memory 110 and the display 112. The screen 112 then provides a visual representation of the energy consumption counter information from which readings can be taken by the staff of the electric company. The non-volatile memory 110 stores the energy consumption counter information for retention purposes in the event of a power interruption.

Optionally, the controller 108 further provides information to the power consumption meter, as well as other information to the communication port 114. The communication port 114 can then communicate information about an external communication medium, such as a public telephone network, to a central processing facility for the utility. In this way, the utility can raise and bill the energy consumption recorded by the meter 10 without requiring an employee to physically see the meter. Additionally, the controller 108 has the ability to provide alternative energy information, such as VA, VAR and energy factor. The VA amount is the amount of well-known energy consumption that is, in some circumstances, more accurate than the watts measured to quantify the electrical energy actually consumed by a consumer. The controller 108 is operable to determine such alternative energy information, which includes VA, using methods well known in the art. The controller 108 also generally controls the operation of the measurement circuit 104 and particularly the first, second and third multiplexers 116, 118 and 120, respectively, to the first, second and third converters 122., 124 and 126 A / D, respectively, and to the digital signal processor 128. For this purpose, the processor provides synchronization signals and other control signals to various elements of the conversion circuit 106 as necessary to carry out the operations described above. By controlling the operation of the measurement circuit 104, the controller 108 can perform compensation if a wiring error is detected. The operation of the controller 108 to carry out compensation is discussed in more detail below, in relation to figures 7, 8 and 9. In addition to generating energy consumption data, the DSP 128 also determines and provides other information to the controller 108. In particular, the DSP 128 provides for each phase, the measured voltage and current magnitude data, and the measured voltage and current phase angle data. The data of measured voltage and current magnitude typically represent the values per RMS phase. The data of measured voltage and current phase angle typically represent the phase angle of each phase voltage and the current with respect to the base phasor, for example VA. To determine the measured voltage and current magnitude data, the DSP 128 performs an RMS calculation with respect to each digital voltage and current measurement signal. This calculation, for example, may include the following steps: multiply each of the digital current measurement signal samples by each of the digital voltage measurement signal samples for each phase, in order to produce high samples to the square; take the average of the samples squared with respect to time; and then take the square root of the resulting mean. To determine the phase angle data for each phase voltage, the DSP 128 determines the time differences between the zero crossings of the voltage signals. The time difference between a zero crossing of a particular signal and the signal that is used as the base phasor, and the direction of the respective zero crossings, provides phase information. In the exemplary embodiment described herein, VA is used as the base phasor. Consequently, the phase angle of VB is measured to obtain the time difference of the zero crossing between VA and VB, as well as the direction of the crossing. To determine the phase angle data for each phase current, the DSP 128 first determines the wattsx and the VARX for each phase x. The watts per phase are calculated using the energy calculation based on the product of DIG__VX and DIG__IX for each phase x. The VAR per phase is calculated based on the product of DIG_VX and DIG__VX (-90 °) for each phase x. In the exemplary embodiment herein, the DSP 128 provides the VARX and wattsx data, which contains the current phase angle information, to the controller 108. The controller 108, as described below, actually calculates the values of phase angle measured from this data. Once the controller receives the measured voltage and current magnitude and phase angle data from the DSP 128, the controller 108 then determines the measured voltage and current magnitude and the phase angle values. Table 1, below, shows each measured value determined by control 108.

Table 1 VRMS, phase voltage magnitude A VRMSB = phase voltage magnitude B VRMSC phase voltage quantity C IRMS, phase current magnitude A IRMSB phase current quantity B IRMSC = phase current magnitude C v < A = Phase voltage phase angle A V < B = Phase voltage phase angle B V < c = Phase voltage phase angle C I < A = phase current phase angle A I < B = phase current phase angle B I < c = Phase current phase angle C It is noted that the processor does not need to perform additional calculations to the measured voltage and current magnitude data to obtain the corresponding measured values, since the DSP 128 has already provided the data in the format of magnitude RMS. However, in the present embodiment, the controller 108 must perform additional calculations to determine the measured voltage and current phase angle values from the measured voltage and current phase angle data. In particular, the measured voltage phase angle voltage data consists of a series of data with zero crossing which are converted to phase angle values. Those usually familiar with the art will easily program the controller 108 to perform such conversion. The measured current phase angle data consist of VARX and attsx, which the controller 108 converts to phase angle values using the I <equation; x = arctan (VARX / attsx). Alternatively, it is considered that DSP 128 can be configured to provide the measured voltage and current phase angle data in the measured value format shown in Table 1. As will become more readily apparent from the following, the controller 108 uses the measured values of table 1 in the diagnosis and compensation of measurement errors. It is also noted that in the types of service that include a neutral line, the RMS current of the neutral line IRMSN can be determined by adding the other currents together. Therefore, in a four-wire Y-shaped wiring configuration, IRMSN = IRMSA + IRMSB + IRMSC. Figure 5 shows a flowchart of the general operations of the processor of an electric utility meter, according to the present invention. In particular, the controller 108 first initializes the measurement circuit 104 to operate using an implicit configuration (step 502). The implicit configuration consists of, among other things, the multiplexing scheme of the multiplexers 116, 118 and 120, the ENERGY calculations, the VAR calculations, and the calculations of measured voltage and current and phase magnitude, and other calculations made by the DSP 128, the controller 108 or some combination of both, the DSP 128 and the controller 108. In the present embodiment, the controller initializes the measurement circuit 104 to operate as described above in relation to FIG. 4. the controller 108 obtains measured values from the conversion circuit 106 (step 504). The measured values can include measured voltage magnitude, voltage phase angle, current magnitude or current phase angle values, or any combination thereof. The controller 108 uses the measured values to determine the type of service to which the meter is connected, or type of service present (step 506). The controller 108 determines the type of service present automatically, as described below in the following, in connection with Figure 6. A suitable service type recognition feature that can be easily incorporated in the present embodiment is described in the patent application. of the original United States (parent) serial number 08 / 690,973, incorporated herein by reference. Once the type of service is recognized, the meter can self-configure to perform measurements for the recognized type of service and then continue the measurement as described above in relation to figure 4. For example, because different calculations are necessary for Measuring three wire delta wiring configurations and four wire Y wire wiring configurations, the meter needs to autoconfigure itself to perform appropriate measurements for the recognized type of service. In an alternative mode, the meter may be limited to a particular type of service, or it may be manually configured for a particular type of service.

In some systems, the type of service is predetermined for a meter when adjusting the splice conductors or when configuring a DIP switch. In such alternative meter, steps 504 and 506 are unnecessary. However, the automatic recognition of type of service greatly improves the versatility of the meter, because it does not require personnel to install special programming or preconfiguration in the factory. In any case, the controller 108 subsequently periodically performs diagnostics to determine if a wiring error is present, and effects a compensation if a wiring error is detected (block 508). In particular, the controller 108 first obtains new measured values from the conversion circuit and compares the values with the set of expected values corresponding to the type of service present (step 510). The measured values may include the same values described above in relation to step 504, or may include more or fewer values, based on the diagnostic capabilities of the meter. In the present embodiment, the measured values used for diagnosis include all voltage and current and phase magnitude values. Subsequently, the controller 108 determines whether an error is present (step 512). For this purpose, the controller 108 determines whether each of the measured values is within a tolerance or range acceptable for the corresponding expected value. If no error is detected, then the controller 108 continues to perform measurement functions and waits for the next periodic diagnostic check (step 508). However, if an error is detected, then the controller 108 performs an automatic adjustment as further described below (step 514). Consider, for example, a meter installed in a four-wire, 120-volt Y type of service, such as the one illustrated in figure 1. The expected values (with tolerances) are: VRMSA = VRMSB = VRMSC = 120 vrms (96 vrms to 138 vrms); V < A = 0 ° (reference); V < B = 120 ° ± 10 °; V < c = 240 ° ± 10 °; I < A = 0 ° + 90 °; I < B = 120 ° + 90 °; and I < c = 240 ° ± 90 °. It is noted that values of magnitude of current are generally not expected because the current consumption varies from one user to another. However, a provision may be made for the user to define values of expected current magnitude for a particular application. In any case, if the measured values for VRMSA, VRMSB, VRMSC, V < A, V < B, V < c, I < A, I < B and I < c are all within the expected intervals, then no error is detected. However, if one or more values are not within the expected ranges, then a wiring error is indicated. For example, if the value V < c is not between 230 ° and 250 °, but rather has a value of 60 °, then the controller 108 detects an error. Under these circumstances, the controller 108 can determine that the phase voltage connection C is 180 ° out of phase. Such reading indicates the existence of an error in the voltage polarity on the voltage measurement sensor of phase C, as illustrated in figures 2 and 2a. Returning to the general description of figure 4, if an error is present, then the controller 108 makes an adjustment (step 514) to the measurement circuit 104, and typically to the conversion circuit 106 (see FIG. 4). The adjustment effects a compensation that corresponds to the detected error, and serves to increase the accuracy of the meter. In the example described above, in which the polarity in Vc is reversed, the controller 108 would perform compensation by providing control signals to one or more elements of the measurement circuit 104 to compensate for polarity reversal. For example, the controller 108 may provide a signal to the DSP 128 which causes the DSP 128 to grade all the DIG_VC samples by a factor of -1. Figure 6 shows in more detail the operations of a controlled meter in an exemplary implementation of the present invention. In this implementation - 35 - of course, configure the measurement circuit to make measurements and energy calculations for a different wiring configuration. Once the measurement circuit is initialized, the controller establishes two flags: GoodSvcType = 0, which represents that a good type of service has not yet been identified.; and DoSSCAN = 1, which represents that SSCAN has been performed (step 404). Subsequently, the controller starts the main circuit. In the first stage of the main circuit (step 406), the controller determines whether the new measured voltage quantity (and current) and phase angle data, or simply measured data, are ready. The new measured data is typically provided by the conversion circuit every 300 milliseconds. The 300 millisecond time interval allows enough voltage samples to accumulate to perform characteristic RMS magnitude calculations. It will be appreciated that the exact time period is given by way of example only. If new measured data is ready, then the controller then processes various energy and demand variables (step 408). Electronic meters currently often offer capabilities to measure many aspects of measured energy demand. The various energy and demand variables required to provide these capabilities are typically updated - 36 - when each set of new measured data becomes available. After the energy and demand variables have been processed, the controller determines the status of the DoSSCAN flag (step 410). If the flag (1) has been placed, then the controller performs the SSCAN routine (step 412). The SSCAN routine of step 412 attempts to determine the type of service using the measured voltage magnitude and the phase data. To do this, the controller compares the measured voltage magnitude and the phase data with expected values. Figure 10 shows a table of expected values. Each entry in table 10 of figure 10 identifies expected values for a particular type of service. If the measured values are sufficiently similar to a set of the expected values, then the meter operates under the type of service corresponding to the set of expected values, and the GoodSvcType (1) flag is placed. However, if the measured values are not sufficiently similar to any of the set of expected values, but a pre-existing service type has been stored in the meter, then the meter proceeds under the pre-existing service type but does not set the GoodSvcType flag. Finally, if the measured values are not sufficiently similar to any of the set of expected values, and a pre-existing service type has not been stored, then an unknown type of service error is placed. A complete explanation of the suitable routine that can be used as the SSCAN routine of step 412 can be found in the application for United States patent serial number 08 / 690,973. When the SSCAN routine has been completed, the controller resets the SSCAN flag to 0 (step 414) and advances to step 416. With reference again to step 410, if the controller determines that the SSCAN flag (0) has been cleared, then the controller proceeds directly to step 416. In step 416, the controller determines whether there is an unknown service type error. If there is no unknown type of service error, then the controller can use the known type of service to perform diagnostic routines (step 418) and return to the beginning of the main circuit (step 406). The diagnostic routines are discussed in more detail later in relation to Figures 7, 7a, 8 and 9. If there is an unknown type of service error, then the controller skips the diagnosis and returns directly from step 416 to the stage 406. With reference again to step 406, if the controller determines that new data - 38 - measured is not ready, then the controller, in turn, executes one or more sequences or events of real-time programming elements. Real-time events include operations performed by the controller at specified or regular time intervals. One such real-time event is a SSCAN re-verification, in the present modality every minute is produced. Specifically, if the new measured data is not ready (step 406), then the controller first determines if one minute has elapsed since the last SSCAN re-verification (step 420). Such SSCAN verification is preferably reverified every minute in order to provide a time buffer during the activation of the meter. For example, in heavy duty measurement forms, such as four-wire delta 480 volt forms, the meter is activated one phase at a time, and may require several minutes to activate. In such a meter, the controller can be activated when the first phase is activated, and you can try to perform SSCAN several minutes before the other phases are in operation. When the controller performs SSCAN before all phases are activated, the controller will not be able to recognize the type of service. If one minute has not elapsed since the last SSCAN re-verification, then the controller skips the SSCAN-39-check and proceeds to execute other real-time events (step 422). However, if one minute has passed since the last SSCAN re-verification, then the controller determines the status of the GoodSvcType flag (step 424). If the GoodSvcType (1) flag has been set then the SSCAN routine does not need to be executed, and the controller proceeds to execute other real-time events (step 422). However, if the GoodSvcType flag (0) has been erased indicating that the service type has not yet been correctly identified, then the controller sets the DoSSCAN flag to 1 (step 426). With the DoSSCAN flag placed, the controller will perform SSCAN after the next time the controller executes step 410. In any case, after step 426, the controller advances to execute the other events in real time and, specifically, functions of normal measurement (step 422). The other events in real time include other routines that the controller performs at regular time intervals. For example, the other real-time events include functions such as display processing, usage protocol verification time, demand interval processing, and communications. The implementation and details of such other real-time events are beyond the scope of the invention, and can easily be incorporated by a person usually familiar with the art. - 40 - Figures 7, 7a, 8 and 9 show detailed flowcharts of the operations performed by an electric utility meter controller to detect wiring errors and perform compensations to detect wiring errors. In general, the flow diagram in Figures 7, 7a, 8 and 9 illustrates the diagnosis and correction of several common meter wiring errors, including lost voltage, voltage polarity reversal, current polarity reversal and cross phase . The flow diagram of Figures 7, 7a, 8 and 9 represents in more detail the diagnostic routine of step 418 of Figure 6.

Lost Voltage Error The diagnostic routine begins with step 650 of figure 7. Figure 7 shows a flow diagram of the portion of the diagnostic routine that detects and effects compensation for a wiring error that causes a lost voltage measurement. An example of such a wiring error can be illustrated by the reference to FIG. 1. With reference to FIG. 1, a measurement of lost voltage can be presented when one of the phase voltage sensors A, B or B, 28 and 30. C respectively, it does not connect to its corresponding power line. - 41 - With reference again to Figure 7, in step 650, the controller determines whether the measured voltage magnitude values correspond to their expected values. The measured voltage magnitude values for a 9S meter form consist of VRMSA, VRMSB and VRMSC. In other forms of meter, such as 5S meter forms, phase B is not measured and therefore VRMSB need not be included. The expected values are values for a plurality of service types and are stored within the memory, such as the memory 110 of Figure 4. For example, Figure 10 shows a table of expected values for a plurality of service types in which uses the form of 9S meter. It is considered that the measured values coincide, or agree with the expected values if each measured value is within a predefined tolerance level of its corresponding expected value. Those usually familiar with the technique can select appropriate tolerance levels. If each of the measured voltage magnitude values match (within tolerance) with their corresponding expected values or, in other words, match, then the controller proceeds to perform additional diagnostics to determine if any wiring error is present (stage 702) of Figure 7a). - 42 - However, if the measured values do not match, then the controller first determines if any of the phase voltage measurements have been lost while its respective phase current is still present (step 652). For this purpose, the controller first determines if there is a phase that has a measured current value different from zero, IRMSX = 0, but an unmeasured voltage value, VRMSX. If no voltage measurements have been lost while the current is present, then the controller returns to continue its normal measurement functions (step 660). In such a case, the controller can properly place an error flag and cause that error to be displayed. However, if the controller determines that a voltage measurement has been lost then the controller then determines whether a GoodSvcType flag has been established (step 654). As discussed above in relation to step 412 of FIG. 6, the controller is operable to determine the type of service upon activation using an SSCAN routine. If the type of service is identified in step 402, then a GoodSvcType flag is placed. However, in some instances, a meter can be moved from one position to another, and then installed in a different type of service. In such a case, the SSCAN routine (step 412 of figure 6) may not recognize - 43 - the type of service when the meter has been activated. Although the type of service may not be recognized, the controller will retain the previously determined type of service and may not place the GoodSvcType flag. The GoodSvcType flag is verified in step 654 in order to handle situations in which the meter moves to a different type of service and there is a lost voltage wiring error. Accordingly, if the GoodSvcType flag is equal to 0, then the controller determines the type of service and replaces the lost voltage measurement (step 656). In particular, the controller determines the type of service and replaces the lost voltage measurement using the following method. The controller first takes a first type of candidate service from the service type table. As discussed above, the service type table can be stored in a memory and can contain data similar to those illustrated in Figure 10. Subsequently, the controller replaces the value of the lost voltage, VRMSX with an appropriate value from the table for the first type of candidate service. Subsequently, the controller performs the SSCAN routine to determine if the addition of the VRMSX value allows the type of service to be recognized. If so, then the recognized type of service becomes the new type of service, and - 44 - the controller replaces the identified lost voltage. The lost voltage is replaced in the manner described below, in relation to step 658. Subsequently, the controller can return to its normal operations (step 660). If the addition of the VRMSX value does not allow the recognition of the type of service, then the controller selects a second type of candidate service and repeats the previous steps of: replacing the lost VRMSX voltage with the appropriate value of the second candidate service type; and performs the SSCAN routine. The process can be repeated until all the possible VRMSX values that are appropriate for the various types of service have been replaced and SSCAN has been performed. For example, consider the situation in which VRMSA = 277, VRMSB = 277, VRMSC = 0 and GoodSvcType = 0. In step 656, the controller will select a first type of candidate service from a service type table, such as the service type 4 Y-120 V of figure 10. Subsequently the controller will replace the lost voltage value VRMSC with 120V, and then perform SSCAN. The SSCAN routine in such case may not successfully recognize the service type because VRMSA = 227, VRMSB = 227, VRMSC = 120. Accordingly, the controller will select a second type of candidate service, such as service type 4 Y-277V. The controller will replace VRMSC with 277 and perform - 45 - again SSCAN. The SSCAN routine will subsequently successfully recognize service type 4 Y-277V because VRMSC equals 277. As a result, in such an example, the controller will perform a compensation to replace the phase C voltage measurement with a form of 277 volt alternating current wave. The above process beginning with step 656 represents an important aspect of the present invention. This process allows an unrecognized type of service that has also lost a phase voltage to be recognized and corrected subsequently. Referring again to step 654, if GoodSvcType then the controller advances to step 658. In step 658, the controller performs an adjustment that operates to replace a lost voltage. For this purpose, the controller controls the operation of the conversion circuit, so that the conversion circuit 106 makes the adjustment to replace the lost voltage. Specifically, to perform the appropriate power measurement calculations, the meter requires that the actual voltage waveform be replaced. To replace the waveform, the controller causes the conversion circuit to generate a substitute digital measurement signal for the lost phase voltage using versions - 46 - adjusted and / or combined of at least one of the digital measurement signals of different phase voltage. In order to carry out such substitution, it is noted that each digital phase measurement signal can be expressed as a phase version biased from another digital phase voltage measurement signal or a combination of two other digital voltage measurement signals of phase. For example, any voltage phase signal of a four-wire Y-wiring configuration can be replaced by the inverted sum of the two remaining phase voltage signals. Therefore, VA can be expressed as: VA = - (VB + Vc). In this case, the controller will cause DSP to replace the negative sum of the samples of phase B and phase C in any term of the energy equation that normally requires the samples of phase A. For example, the calculation of Energy in watts can be calculated by the DSP using the following equation: (3) ENERGY = - (CAL_VB DIG_VB + CAL_VC DIG_VC) * (CAL_IA DIG_IA) + (CAL_VB DIG_VB) * (CAL_IB DIG_IB) + (CAL_VC DIG_VC) * (CAL_IA DIG__IA) - (CAL_VB DIG_VB + CAL_VC DIG_VB) * (CAL_IA DIG_IA ) + (CAL_VB DIG_VB) * (CAL_IB DIG_IB) + ... - 47 - The above calculation can be performed by the conversion circuit 106 illustrated in Figure 4 in the manner described below. With reference to Figure 4, it is noted that to implement the above energy calculation, the samples DIG_VB and DIG_VC must be provided to the DSP 128 simultaneously. To accomplish this, the third multiplexer 120 and the third A / 126 converter are used to convert and provide a second simultaneous voltage sample to the DSP 128. Specifically, to carry out the above exemplary equation, where the voltage of the phase A, the second multiplexer 118 must not select voltage measurement signals from each of the three voltage sensors 26, 28 and 30, in one phase rotation: A, B, C, A, B, C, A , ..., and this is done in normal operation. Instead, the second multiplexer 118 selects the voltage measurement signals of the next phase rotation: B, B, C, B, B, C, B .... Cooperatively, the third multiplexer 120 selects the voltage measurement signals in the next rotation: C, X, X, C, X, X, C ... (where X is a "unimportant" value). In this way, the voltage signals of B and C can be converted simultaneously by the second A / D 124 and the third A / D 126 and are provided to the DSP 128 in the time interval normally assigned to the voltage measurement signals. of phase A. - 48 - Although the previous example illustrates the adjustments to the conversion circuit 106 that are necessary to replace the lost phase A voltage measurement signal, those familiar with the art can easily apply the prior techniques to the replacement of the signals of voltage measurement of phase B and phase C. Referring again to FIG. 7, the controller in step 658 may use related techniques to replace the voltages in a delta four wire wiring configuration. For example, a phase A voltage signal can be substituted by simply replacing an inverted phase B voltage signal. The controller simply makes the appropriate adjustment to replace the lost voltage based on the type of service. Once the controller has made the appropriate adjustments to replace the lost voltage, the controller can return to normal operations (step 660). It is noted that other methods can be used to replace a lost voltage signal. For example, the conversion circuit or a meter measurement circuit may include a memory in which a look-up table consisting of a sequence of digital voltage measurement samples 49 is stored corresponding to a sinus shape of 120, 277, 240 or 480 volts. In such a case, the conversion circuit may use the memory samples, inserted in the appropriate phase relationship, to replace a phase of lost voltage.

Voltage Polarity Error Figure 7a shows the flow of operations that are executed by the processor if, in step 650 of Figure 7, the controller determines that all measured voltage magnitude values coincide. Figure 7a shows a flow chart of the diagnostic routine that identifies and carries out compensation for a reversal of voltage polarity. There is an inversion of voltage polarity, for example, when a voltage sensor of a meter is illuminated wrongly. Figures 2 and 2a illustrate an example of a poorly wired phase C voltage sensor 30 which results in a voltage polarity error. In operation, the controller first determines whether the measured voltage phase angle values correspond to their expected values (step 702). For example, the voltage phase angle values measured for a meter form 9S consist of V < A, V < B and V < c. - 50 - Similar to the expected magnitude values, the expected phase angle values are stored within the memory such as the memory 110 of Figure 4. For example, Figure 10 shows a table of expected phase angle values for a plurality of service types in which the 9S meter form is used. Similar to the measured voltage magnitude values, the measured voltage phase angle values are considered to coincide with the expected values if each measured value is within a predefined tolerance level of its corresponding expected value. Those usually familiar with the art can select suitable tolerance levels. If the measured phase angle values match, then the controller proceeds to perform additional diagnostics to determine if any other type of wiring error is present (step 706). However, if the measured phase angle values do not match, then a wiring error is indicated, and the controller proceeds with the diagnosis and compensation for the wiring error. In general, the controller identifies whether there is a phase voltage polarity error, or in other words, if any of V < A, V < B or V < c is approximately 180 ° out of phase. For this end-51, the controller executes the steps of the flow chart beginning with step 704. In step 704, the controller determines whether the reversal of the phase of the voltage measurement of phase A can produce values of voltage angle measured in accordance. For this purpose, the processor adds (or subtracts) 180 ° from the values V < B and V < c and again compare these values with the expected values. Because V < A is generally used as the reference phase angle, which is always 0 °, when inverting V < B and V < c provides a sufficient approximation of the investment effects of V < A. If the comparison of V < B and V < Inverted indicates that the measured voltage phase angles do not match, then a voltage polarity error is indicated, and the controller proceeds to carry out a compensation for the voltage polarity error (step 708). However, if not, then the controller continues his diagnosis (step 712). In step 708, the controller effects compensation by altering the configuration of the measuring circuit of the meter or the conversion circuit in such a way that voltage measurements A are reversed in phase. This can be done in many ways, which they include, for example, multiplying the samples of the digital voltage measurement signal of phase A by -1. In the exemplary embodiment described in Figure 4, the controller -52-108 can suitably provide a control signal to the DSP 128 and cause the DSP 128 to insert a multiplier -1 in equation (1) only for phase A The multiplier -1 can be inserted in the calculation of phase A by multiplying the calibration constant of phase A, CALA, by -1. It is noted that the reversal of phase voltage polarity using the method described above in relation to steps 704 and 708 will compensate for the two different types of wiring errors. The first type of wiring error that is compensated for by reversing the phase voltage polarity is an error in which the wiring of the voltage sensor that corresponds to the compensated phase voltage is reversed. For example, the compensation of the voltage measurement A will compensate for a wiring error in which the voltage sensor of phase A has been wired inversely. The second wiring error that can be compensated in steps 704 and 708 is a situation in which all of the phase voltage sensor devices except that corresponding to the compensated phase voltage are wired backwards. In other words, if the phase B and phase C voltage sensors are wired backward, step 704 and step 708 will effectively reverse the polarity of the voltage measurement of phase A. However, in such case, does - 53 - note that although the measured angles compensated, V <; A, V < B, and V < c appear to have the correct angular relationship, in fact they are all 180 ° out of phase. Such a situation can cause errors in the subsequent energy consumption calculations. Steps 720, 721, 723 and 724, described in the following, solve this situation to avoid such errors. To assist in the detection of the effective reversal of all voltage phases in steps 720, 721, 723 and 724, the controller sets a compensation, or flag COMP = 1, one to indicate that it has been reversed at least a phase voltage measurement signal, which indicates the possibility that all three phase voltages are 180 ° out of phase. Then the controller returns to normal operations (step 710). In other words, the controller proceeds from step 618, as shown in FIG. 6, as discussed above. Referring again to step 704, if it is determined that the reversal of the VA phase does not produce matching measured voltage values, then the controller determines whether the reversal of the VB phase can produce matching values. (step 712). Accordingly, in step 712, the controller adds (or subtracts) 180 ° from the value V < B measured and returns to compare the - 54 - value with its corresponding expected value. If the recomparation makes it evident that each of the measured values, including V < B adjusted match, then a polarity error is indicated for VB, and the controller proceeds to carry out a compensation for the voltage polarity error (step 714). However, if not, the controller continues his diagnosis (step 716). In step 714, the controller carries out the compensation by altering the configuration of the meter measurement circuit so that the phase B voltage measurements are reversed. This can be accomplished by causing the signal samples voltage measurement of phase B are multiplied by a factor of -1, analogous to the technique described above for the comparison of a phase inversion VA in step 708. Once the controller carries out the compensation, the controller then set the flag COMP equal to 1 (step 719), and return to its normal operations (step 710). In other words, the controller proceeds from step 418, as shown in FIG. 6 and is discussed in the foregoing. If, in step 712, it is determined that the reversal of the VB phase does not produce matching measured voltage values, then the controller determines whether the reversal of the Vc phase would produce matching values. - (step 716). Consequently, the controller adds (or subtracts) 180 ° from the value V < c measured and again compare the value with its corresponding expected value. If the recomparison shows that each of the measured values agrees, including V < c set, then voltage polarity error for Vc is indicated, and the controller advances to carry out a compensation for the voltage polarity error (step 718). In step 718, the controller carries out the compensation by altering the configuration of the meter measurement circuit so that the phase of the voltage meters of phase B is reversed. This can be carried out in a suitably analogous manner. to that described above for the compensation of phase investments VA and VB in steps 708 and 714, respectively. Once the controller carries out the compensation, the controller then adjusts the COMP flag equal to 1 (step 719), and returns to its normal operations (step 710). In other words, the controller proceeds from step 418 as shown in figure 6 and is discussed in the foregoing. It is noted that some of the meter forms do not include a measurement of phase B for both voltage and current. It will be appreciated that the above flow chart can be used appropriately in such a situation. The only effect of the absence of phase B would be that - 56 - you would have to make sure that the answer in step 712 is negative. As a result, the flow chart will operate as if step 714 did not exist. However, if, in step 716, it is determined that the reversal of phase Vc does not produce measured voltage phase angle values that match, then the controller continues with the diagnosis and proceeds to execute step 802, in figure 8. Again with reference to figure 7a and in particular to step 702, if the controller determines that each of the phase angle values of measured voltages agrees, then the controller performs additional diagnostics beginning with step 706. In step 706, the controller determines whether current phase angles I <; A, I < B and i < c are within the acceptable range of the corresponding voltage phase angles, I < A, I < B and i < c respectively. According to the present embodiment, a current I < x is within an acceptable range of V < x your I < x is within ± 90 ° of V < x. The use of ± 90 ° is an acceptable range that allows a wide range of loads in a measured electrical system. For example, some charges are almost completely inductive in nature, causing a variance of almost 90 ° between the corresponding current and the voltage phase angles. If the acceptable window is relatively narrow, such loads could cause the diagnostic routine to erroneously detect a wiring error. If all of the current phase angles are within the acceptable range or, in other words, they agree, then no wiring error is indicated and the controller completes the diagnostic routine and returns to its normal measurement operations, as shown in Figure 6. However, if at least one current phase angle does not match, then the controller continues with the diagnosis. In particular, the controller determines when there is a current polarity error in all of the phases (step 720). A polarity error in all phases of current can occur for various reasons. For example, the current sensors in the meter can all be wired transversely. However, polarity reversal in all phases is more likely to be caused by a prior compensation of a voltage polarity reversal in steps 706, 712 or 716 as discussed above in relation to step 719. Specifically, if If two of the three voltage sensors are badly wired, the controller, operating in accordance with steps 708, 712, 714 and 718, will effectively invert the phase of the digital voltage measurement signal in the other phase, thereby causing the measurement signals of the digital voltage of all three phases are 180 ° out of phase. In such a case, the current phase angles and the voltage phase angles would all be (approximately) 180 out of phase with each other. Going back to the general description of the figure 7, in step 720, the controller determines without the addition (or subtraction) 180 ° of all I < A, I < B and i < c would produce measured current values that match. If this is not the case, the controller continues with the diagnosis beginning with step 802 of FIG. 8. However, if the inversion of all the current phase angles can produce a match, then the controller determines whether the compensation flag COMP is set equal to 1 (step 721). Without the answer in step 721 it is yes, then the controller carries out a reversal of compensation of all of the voltage phase angles. Specifically, if the controller determines that all of the measured voltage phase angle values are 180 ° out of phase with their corresponding current phase angle values (step 720) and that the voltage phase angle has been compensated for. (step 721), then the controller defines that the voltage phase angle values, in the manner in which they are compensated, are all 180 ° out of phase. Therefore, the controller carries out the inversion compensation of all of the voltage phase-59-angles. However, if in step 721 it is determined that the flag COMP has not been set equal to 1, then the controller carries out a compensation inversion of all the current phase angles. Once the controller has performed the compensation, the controller returns to normal measurement operations (step 710).

Cross Phases Error Figure 8 shows a continuation of the diagnostic routine flow diagram started in Figure 7, described above. In general, the portion of the flow chart shown in Figure 8 detects and compensates for wiring errors defined as cross phase errors, such as exemplified in Figures 3 and 3a. There are three possibilities of cross-phase errors: one in which I < A and I < B are exchanged, one in which I < A and I < c are exchanged, and one in which I < B and I < c are exchanged. It is also noted that, because V < A is always the reference angle, the cross phase errors in the voltage can only vary in the order of the phases, if it is ABC or CBA. Such variances are tolerated and can be properly considered as part of the definition of the type of service. Consequently, if there is - 60 - a cross-phase voltage situation, it is not considered to be a wiring error. Instead, the controller only determines that the service type includes a CBA phase order, as shown in Figure 10. In any case, the controller executes the operations illustrated in Figure 8 to detect and compensate the three possible cross-phase current errors. The controller first determines whether I < A is within its acceptable range, or in other words, within ± 90 ° of V < A (step 802). If so, then no cross-phase error including AI is indicated and the controller proceeds to step 814, described further below. However, if not, then a cross-phase error may be indicated and the controller then determines whether the switching of I < A and I < B will produce appropriate values (step 804). For this purpose, the controller determines whether I < As measured, it is within ± 90 ° of V < B and I < c, as measured, and if they are within + 90 ° of V < A. If so, then the controller makes a compensation that corrects the cross phases of I < A and IB (step 806). In the exemplary embodiment of Figure 4, the controller can perform the compensation by providing control signals to the first multiplexer 116 and the second multiplexer 118. The control signals cause the second multiplexer 118 to provide the samples - 61 -DIG_IB of the DSP 128 (through the 124 A / D converter) contemporaneous with the delivery of the DIG_VA samples through the converter 122 (A / D) to the DSP 128 via the first multiplexer 116. The control signals also cause the second multiplexer 118 to provide the DIG_A samples of the DSP 128 contemporaneous with the supply of the DIG_VB samples to the DSP 128 by the first multiplexer 116. As described in the above, the DSP 128 performs the energy measurement described in equation (1) by multiplying the current and voltage samples that arrive in a contemporary manner. As a result of the compensation, DSP 128 can multiply DIG_VA by DIG_IB as received, and DIG_VB by DIG_IA as received. In other words, DSP 128 effectively performs the following revised energy measurement: (4) ENERGY = VAIB + VBIA + VCIC Preferably, the controller provides another control signal that switches any calibration constant associated with IA and IB so that the constants are applied to the appropriate DIG_V * DIG_I multiplication. The compensation described above substantially reduces and effectively eliminates any errors introduced to the measurement -62- of meter power consumption caused by a cross-phase wiring error. Returning again to the discussion of the flow chart of Figure 8, in step 804 it is determined that the I < A and I < B would not produce a set of matching phase angle values, then the controller then determines whether the switching of I > A and I > B will produce appropriate values (step 810). For this purpose, the controller determines whether I < A, as measured, is within ± 90 ° of V < c and I < c as measured, is within + 90 ° of V < A. If both conditions are satisfied, then the controller effects a compensation that corrects the cross phase of I < A and I < c (step 812). To carry out the compensation in the exemplary mode of an electric utility meter as shown in Figure 4, the controller 108 provides control signals that cause the first multiplexer 116 to provide the samples DIG_IC to the DSP 128 (through the converter 122 A / D) contemporary to the provision of DIG_VA samples to DSP 128, and vice versa. Accordingly, the DSP 128 performs the calculation effectively: (5) ENERGY = VAIC + VBIB + VCIA - 63 - Once the controller performs the compensation, the controller returns to the usual measurement operations (step 808). However, if in step 810 it is determined that the investment of I < A and I < c do not produce matching current phase angle values, then a cross-phase error involving IA is not indicated. Accordingly, the controller performs additional diagnostics to determine the cause of the mismatch of the measured value for I < A beginning with step 902 of figure 9, described further below. Referring again to step 802, if I < A is within ± 90 ° of V < A, then the controller determines if I < B is within ± 90 ° of V < B (step 814). If so, no cross-phase errors are indicated because I < A nor I < B appear to be in the cross phase. Accordingly, if the answer to the question in step 814 is affirmative, the controller proceeds to step 912 of figure 9, described further below. However, if it is determined that I < B is not within ± 90 ° of V < B, then the controller determines whether the exchange of I < B and I < c will produce values of matching current phase angles (step 816). To make this determination, as in the above, the controller determines whether I < B as measured, is within ± 90 ° of V < c e - 64 -I < c as measured, is within ± 90 ° of V < B. If both conditions are satisfied, then a cross phase error is indicated for I < B and I < c and the controller performs a compensation that corrects the cross-phase error (step 818). To carry out the compensation in the exemplary embodiment of an electric company meter shown in Figure 4, the controller 108 provides a control signal that causes the first multiplexer 116 to provide the DIG_IC samples to the DSP 128 contemporaneous with the supply of the samples. from DIG_VB to DSP 128 and vice versa. Accordingly, the DSP 128 performs the calculation effectively: (6) ENERGY = VAIA + VBIC + VCIB Once the controller carries out the compensation, the controller returns to the usual measurement operations (step 808). However, if in step 816 the controller determines that the reversal of the phase angle values I < B and I < c do not produce a set of matching angle values, then no cross-phase wiring error is indicated. Then, the controller proceeds to step 908 of Figure 9. - 65 - Current Polarity Error Figure 9 shows a continuation of the diagnostic routine flow diagram started in Figure 7 and continuing in Figures 7a and 8 described above. In general, the portion of the flow chart shown in Figure 9 detects and compensates for wiring errors defined as current polarity errors. A current polarity error is an error in which one or more phase current is 180 ° out of phase. Current polarity errors, like voltage polarity errors, are often caused by poor wiring of the current sensing devices to the power lines of the electrical system being measured. Although current polarity errors are generally identified and compensated during the execution of the flow chart of Figure 9, it is noted that steps 720, 721 and 724 of Figure 7a resolve the detection and compensation for the presentation of an error. of current polarity in all three phases. With reference to FIG. 9, the controller executes step 902 after executing step 810 of FIG. 8. In step 810, the controller has already determined that I < A is not within the acceptable range with respect to V < A. Accordingly, in step 902 of Figure 9, the -66-controller determines whether there is a current polarity error in phase A. For this purpose, the controller determines whether I < A + 180 ° is within ± 90 ° of V < A. It is noted that, in the present embodiment, wherein the acceptable range is within ± 90 ° of V < A, the answer in step 902 should always be yes, and the determination of step 902 should be excluded. More specifically, stage 902 is not reached unless I < A is not within ± 90 ° of V < A and therefore I < A- + 180 ° will always be within ± 90 ° of V < A. However, in other embodiments, such a wide range of acceptable values can not be used and the determination of step 902 may be necessary. If the determination in step 902 is affirmative, then a polarity error is indicated for phase A and the controller performs adequate compensation for it (step 904). The compensation for example, may comprise providing a signal that causes the phase A current samples to be in the inverted phase. Specifically, in the exemplary embodiment of Figure 4, the controller 108 can provide a control signal to the DSP 128 which causes the DSP 128 to multiply all the DIG_IA samples by a factor of -1. Once the compensation is carried out, the controller returns to normal measurement operations (step 906), as illustrated in figure 6. - 67 - If the determination in step 902 is negative, then the controller performs additional diagnostics, not shown, to determine the source of the mismatch of the I < A measured, or simply returns to its normal measurement operations (step 906). The controller executes step 908 after executing step 816 of FIG. 8. In step 816, the controller has already determined that I < A agrees and that I < B does not agree. Accordingly, in step 908 of FIG. 9, the controller determines whether a current polarity error exists over phase B. For this purpose, the controller determines whether I < B + 180 ° is within ± 90 ° of V < B. In the present embodiment, wherein the acceptable range is within ± 90 ° of V < B, then the answer in step 908 should always be yes, and the determination of step 908 can be excluded. However, as discussed above, the determination of step 908 would be necessary if the range of measured current phase angle values that match is less than ± 90 °. If the determination in step 908 is affirmative, then a current polarity error for phase B is indicated and the controller performs the appropriate compensation for it (step 910). The compensation can include, for example, providing a signal that causes the phase B current samples to be in -68 phase-reversed. In the exemplary embodiment of Figure 4, the controller 108 can provide a control signal to the DSP 128 which causes the DSP 128 to multiply all the DIG_IB samples by -1. Once the compensation is carried out, the controller returns to its normal measurement operations (step 906) as illustrated in figure 6. If the determination in step 908 is negative, then the controller can execute additional diagnostics, not shown, to determine the source of the I <value; B that does not match, or simply returns to normal measurement operations (step 906). The controller executes step 912 after executing step 814 of FIG. 8. In step 814, the controller has already determined that I < A and I < B have acceptable values and that I < c does not have an acceptable value (see also steps 706 and 802). Accordingly, in step 912 of Figure 9, the controller determines whether I < c has a polarity error. For this purpose, the controller determines whether I < c + 180 ° is within ± 90 ° of V < c. As in the case in steps 902 and 908, the response in step 902 should always be yes for the present modality. However, as discussed above, it may be necessary to determine step 912 in other modes in which the range of acceptable current phase angle values are less than ± 90 °. If the determination in step 912 is affirmative, then a current polarity error for phase C is indicated and the controller performs the appropriate compensation for it (step 914). The compensation is analogous to that described above in relation to steps 904 and 910. Once the compensation is carried out, the controller returns to normal measurement operations (step 906) as illustrated in figure 6. If the determination in step 912 is negative, then a wiring error has not been successfully diagnosed, and the controller returns to normal measurement operations (step 906). It is noted that the modalities described in the foregoing are only illustrative. Those usually familiar with the art can easily design their own implementations that incorporate the principles of the present invention and that are within the spirit and scope of the same. For example, the operations of the DSP 128 of Figure 4 can be performed by two or more separate digital components. Those usually familiar with the art will easily substitute the DSP with suitable alternative digital processing circuits.

It is noted that in relation to this date, the best method known to the applicant to carry out the aforementioned invention is that which is clear from the present description of the invention. Having described the invention as above, property is claimed as contained in the following:

Claims (59)

- 71 - CLAIMS

1. A method to detect and compensate for a wiring error that alters the measurement of energy consumption of an electric company meter, in an electric utility meter, the electric utility meter is operable to measure the energy consumption, the method is characterized in that it comprises: a) obtaining measured phase angle data for a plurality of phases in a polyphase electrical system; b) periodically perform one or more diagnostic tests using the measured phase angle data to determine if a wiring error is present; and c) Automatically adjust the operation of the electric utility meter to effect compensation for the wiring error, the operation increases the measurement accuracy of power consumption of the electric utility meter. The method according to claim 1, characterized in that step a) further comprises obtaining measured voltage phase angle data, wherein step b) further comprises performing one or more diagnostic tests periodically using the angle data of Measured voltage phase to determine if a voltage polarity error is present, the error - 72 - voltage polarity comprises at least one phase voltage which is approximately 180 ° out of phase, and in which the step c) it also comprises automatically adjusting the operation of the electricity company's meter when compensating for the voltage polarity error. The method according to claim 1, characterized in that step a) further comprises obtaining measured current phase angle data and measured voltage phase angle data, wherein step b) further comprises periodically performing one or further diagnostic tests using the measured voltage phase angle data and the measured current phase angle data to determine whether a cross phase error is present, and wherein step c) further comprises automatically adjusting the operation of the meter the electric company to make a compensation for the cross-phase error. The method according to claim 1, characterized in that step a) further comprises obtaining measured current phase angle data, wherein step b) further comprises performing periodically one or more diagnostic tests used to measure the data of measured current phase angle to determine when a polarity error -73 of current is present, wherein step c) further comprises automatically adjusting the operation of the electric utility meter to carry out a compensation for the polarity error of current. 5. The method according to claim 1, characterized in that step a) further comprises obtaining measured voltage and phase angle data and magnitude and measured current phase angle data, step b) further comprises performing periodically one or more diagnostic tests using the measured voltage and magnitude phase data and the phase angle data, and the measured current phase angle data to determine if one of a plurality of wiring errors is present and further identify the wiring error of a plurality of wiring errors if a wiring error is present and in which step c) further comprises automatically adjusting the operation of the electricity company's meter by compensating for the identified wiring error. The method according to claim 1, characterized in that step a) further includes obtaining data of magnitude of measured voltage, step b) further comprises performing periodically one or more diagnostic tests used to measure the measured voltage magnitude data to determine whether a voltage error is present, and in which the controller is operable additionally to adjust the operation of an electric utility meter to carry out a compensation for the lost voltage error. 7. The method according to claim 1, characterized in that the controller is additionally operable to periodically perform one or more diagnostic tests to obtain expected values from a memory, and compare the measured phase angle data with the expected values. The method according to claim 1, characterized in that it further comprises a step b) of determining a present type of service corresponding to the polyphase electric system of a plurality of possible types of service. The method according to claim 7, characterized in that step a) further comprises obtaining measured voltage magnitude data, and wherein the method further comprises: d) obtaining the expected values for one or more of the plurality of possible types of service from the memory; e) comparing the expected values for one or more of a plurality of possible types of service to the measured data of the measured voltage magnitude and to the measured phase angle data. The method according to claim 1, characterized in that step a) further comprises: receiving current voltage measurement signals of a plurality of phases in a polyphase electrical system; using a digital analog converter to generate digital measurement signals using the current voltage measurement signal, the digital measurement signals include digital voltage measurement signals and digital current measurement signals for each phase of the polyphase electrical system; generating measured data using the digital measurement signals, the measured data comprise measured voltage phase magnitude and angle data and measured current phase magnitude and angle data. The method according to claim 10, characterized in that the digital measurement signals each comprise a sampled waveform including one or more samples, and wherein step a) further comprises generating watt data when multiplying The samples of voltage measurement signal - 76 - digital by the samples of digital current measurement signal for each phase of polyphase electric system. The method according to claim 11, characterized in that step a) further comprises generating measured voltage magnitude data when calculating the square root mean in a plurality of digital voltage measurement signal samples for each phase. The method according to claim 11, characterized in that step a) further comprises generating measured current magnitude data by performing a calculation of the square root measurement on a plurality of digital current measurement signal samples for each phase. The method according to claim 11, characterized in that step a) further comprises generating voltage phase angle data measured using the zero crossings of the digital voltage measurement signals for the plurality of phases in the electrical system polyphase. 15. The method according to claim 11, characterized in that step b) further comprises periodically performing one or more diagnostic tests using the measured data to determine if a voltage polarity error is present, the error - 77 - of polarity of The voltage comprises at least one phase voltage which is approximately 180 ° out of phase, and wherein the controller is operable further to adjust the operation of the utility company meter by effecting a compensation for the voltage polarity error. 16. The method according to claim 15, characterized in that step c) further comprises effecting compensation of the voltage polarity error by causing the digital signal processor to multiply the digital voltage measurement signal samples corresponding to at least one phase of the polyphase electrical system per -1. The method according to claim 11, characterized in that step b) further comprises performing one or more diagnostic tests using the measured data to determine if a cross-phase error is present, the cross-phase error comprises a measurement signal of digital current for a first phase, which corresponds to a second phase of the polyphase electrical system, and a digital current measurement signal so that the second phase corresponds to a first phase of the polyphase electrical system, and in which the controller is operable additionally to adjust - 78 - operation of the electric utility meter to effect a compensation for the cross phase error. 18. The method according to claim 17, characterized in that step c) comprises also perfthe compensation for the cross-phase error by causing the digital signal processor to generate watt data by multiplying the samples of digital current measurement signal of the first phase by the digital voltage measurement signal samples of the second phase and by multiplying the digital voltage measurement signal samples of the first phase by the digital current measurement signal samples of the second phase. 19. The method according to claim 11, characterized in that step b) further comprises performing one or more diagnostic tests using the measured data to determine if the current polarity error is present, and wherein the controller is additionally operable to adjust the operation of the utility company meter carry out a compensation for the current polarity error. 20. The method according to claim 19, characterized in that step c) further comprises effecting the compensation for the error of -79-current polarity by causing the digital signal processor to multiply the voltage measurement signal samples of current corresponding to at least one phase of the polyphase electrical system per -1. 21. A method to detect and identify a wiring error that alters the measurement of energy consumption of a meter of an electric company, in a meter of an electric company, the meter of the electric company is operable to measure the energy consumption , the method is characterized in that it comprises: a) obtaining measured data for a plurality of phases in a polyphase electric system, the measured data comprise magnitude and phase angle data of measured voltage and measured current magnitude and phase angle data; b) automatically identify the type of electric service present based on the measured data; and c) performing one or more diagnostic tests periodically using at least a portion of the measured data and the type of electrical service present to determine if a wiring error is present, and to identify the wiring error of a plurality of wiring errors if a wiring error is detected. - 80 - 2

2. The method according to claim 21, characterized in that it also comprises a step of: d) automatically adjusting the operation of the electric utility meter to effect a compensation for the identified wiring error, the compensation increases a precision in the measurement of energy consumption of the electricity company's meter. 2

3. The method according to claim 21, characterized in that it further comprises a step of: d) displaying information on a meter display that provides an indication corresponding to the identified wiring error. 2

4. An arrangement for use in an electric utility meter, the electric utility meter is operable to be connected to one or more types of electric service, the arrangement is operable to detect and compensate for a wiring error, the arrangement is characterized in that it comprises: a) a conversion circuit for generating an energy consumption measurement and for generating measured phase angle data for a plurality of phases in a polyphase electrical system; b) a memory; and c) a controller operably connected to the memory and the conversion circuit, the processor is operable to receive measured phase angle data for a plurality of phases in a polyphase electrical system, performing one or more diagnostic tests periodically using the measured phase angle data to determine if a wiring error is present, and automatically adjust the operation of the conversion circuit to effect a compensation for the wiring error, the compensation increases the accuracy of the measurement of energy consumption of the meter of the electric company. The arrangement according to claim 24, characterized in that the polyphase electric system includes a plurality of phase voltages and a plurality of phase currents, and wherein the conversion circuit is operable to generate measured phase angle data. using zero crossings of each of the plurality of phase voltages. 26. The arrangement according to claim 24, characterized in that the polyphase electric system includes a plurality of phase voltages and a phase-plurality of the current, and in which the conversion circuit is operable to generate watt data. and VAR data and where the measurement circuit is operable to generate measured phase angle data using the data of watts and VAR data. 27. The array according to claim 24, characterized in that the controller is operable additionally to periodically perform one or more diagnostic tests using the measured phase angle data to determine if a voltage polarity error is present, the polarity error The voltage comprises at least one phase voltage which is approximately 180 ° out of phase, and in which the controller is further operable to adjust the operation of the utility company meter to effect a compensation for the voltage polarity error. The arrangement according to claim 24, characterized in that the controller is further operable to perform one or more diagnostic tests using the measured phase angle data to determine if a cross phase error is present, and in which the controller it is operable additionally to adjust the operation of the utility company meter to effect a compensation for the cross phase error. - The arrangement according to claim 24, characterized in that the controller is operable additionally to perform one or more diagnostic tests using the measured phase angle data to determine if a current polarity error is present, and in that the controller is operable additionally to adjust the operation of the electric utility meter to effect a compensation for the current polarity error. 30. The arrangement according to claim 24, characterized in that the conversion circuit is further operable to generate measured phase voltage magnitude data and measured phase current magnitude data for a plurality of phases in a polyphase electrical system. The arrangement according to claim 30, characterized in that the conversion circuit is further operable to obtain magnitude and phase data of measured voltage angle and measured current magnitude and phase angle data, and where the controller is further operable to receive the measured voltage magnitude and phase angle data and the magnitude and measured current phase angle data, - 84 - periodically perform one or more diagnostic tests using the magnitude and phase angle data of measured voltage and measured current magnitude and phase angle data to determine if one of a plurality of wiring errors is present, to identify the wiring error of a plurality of wiring errors, if a wiring error is present, and adjust the operation of the utility company's meter to effect a compensation for the identified wiring error. 32. An arrangement for use in an electric utility meter, the electric utility meter is operable to be connected to one or more types of electrical service, the arrangement is operable to detect and compensate for a wiring error, the arrangement comprises: a ) a conversion circuit for generating a measurement of energy consumption and for generating measured data, the measured data include magnitude and phase angle data of measured voltage and current and magnitude data and measured current phase angle for a plurality of phases in a polyphase electric system; b) a memory; and c) a connector operably connected to the memory and to the conversion circuit, the processor is operable to receive the measured data for a plurality of phases in a polyphase electrical system, periodically perform one or more diagnostic tests using the measured data to determine if a wiring error is present, and to automatically adjust the operation of the conversion circuit to effect a compensation for the wiring error, the compensation increases the accuracy of the power consumption measurement of the electric utility meter. 33. The arrangement according to claim 32, characterized in that the controller is operable in addition to periodically perform one or more diagnostic tests using the measured data to determine if a voltage polarity error is present, the voltage polarity error comprises at least one phase voltage that is approximately 180 ° out of phase, and wherein the controller is operable in addition to adjust the operation of the utility company's meter to effect compensation for the voltage polarity error. - The arrangement according to claim 32, characterized in that the controller is operable additionally to perform one or more diagnostic tests using the measured data to determine if a cross-phase error is present, and in which the controller is additionally operable to adjust the operation of the electric utility meter to effect a cross-phase error compensation. 3

5. The array according to claim 32, characterized in that the controller is operable in addition to perform one or more diagnostic tests using the measured data to determine if a current polarity error is present, and in which the controller is operable additionally. to adjust the operation of the utility company meter to effect a compensation for the current polarity error. 3

6. The array according to claim 32, characterized in that the controller is operable in addition to perform one or more diagnostic tests using the measured data to determine if a lost voltage error is present, and in which the controller is operable in addition to adjust the operation of the utility company's meter to make a compensation for the lost voltage error. - 87 - The arrangement according to claim 32, characterized in that the controller is further operable to periodically perform one or more diagnostic tests to obtain expected values from the memory and compare the measured data with the expected values. 38. The arrangement according to claim 32, characterized in that the controller is further operable to determine a type of service corresponding to the polyphase electric system of a plurality of possible types of service. 39. The arrangement according to claim 38, characterized in that the memory contains expected values corresponding to the plurality of possible types of service, and the controller is further operable to determine the type of service that corresponds to the polyphase electrical system when obtaining the expected values for one or more of the plurality of possible service types from the memory and comparing the expected values for one or more of the plurality of possible types of service with the measured data. 40. The arrangement according to claim 32, characterized in that the conversion circuit includes at least one analog-to-digital converter ("A / D") operable to receive measurement signals -88- of voltage and current of a plurality. of phases in a polyphase electrical system and generate digital measurement signals, the digital measurement signals include digital voltage measurement signals and digital current measurement signals for each phase of polyphase electrical system, and in which the conversion circuit includes also means for receiving the digital measurement signals and generating the data measured therefrom. 41. The arrangement according to claim 40, characterized in that the digital measurement signals comprise each sampled waveform that includes one or more samples, and wherein the conversion circuits generate watt data by multiplying the signal samples of Digital voltage measurements by digital current measurement signal samples for each phase. 42. The arrangement according to claim 41, characterized in that the means for receiving digital measurement signals and generating measured data is operable to generate measured voltage magnitude data when calculating the mean square root. in a plurality of samples of digital voltage measurement signal for each phase. 43. The arrangement according to claim 42, characterized in that the means for receiving digital measurement signals and generating measured data is operable to generate measured current magnitude data by performing a calculation of the square root mean in a plurality of samples of digital signal of current measurement for each phase. 44. The arrangement according to claim 41, characterized in that the means for receiving digital measurement signals and generating measured data is operable to generate measured voltage phase angle data using the zero crossings of the digital voltage measurement signals for the plurality of phases in the polyphase electrical system . 45. The arrangement according to claim 41, characterized in that the controller is further operable to periodically perform one or more diagnostic tests using the measured data to determine if a voltage polarity error is present, the voltage polarity error comprises at least one phase voltage which is approximately 180 ° out of phase, and in which the controller is further operable to adjust the operation of the electric utility meter by effecting compensation for the voltage polarity error. 46. The arrangement according to claim 45, characterized in that the controller is -operable to carry out the compensation for the voltage polarity error by causing the means to receive the digital measurement signals and generate measurement data. multiply by -1 the samples of digital voltage measurement signal that correspond to at least one phase of the polyphase electrical system. 4

7. The array according to claim 41, characterized in that the controller is further operable to perform one or more diagnostic tests using the measured data to determine if a cross-phase error is present, the cross-phase error comprises a digital signal of measurement of current so that a first phase corresponds to a second phase of the polyphase electrical system, and a digital signal of measurement of current for the second phase, so that it corresponds to a first phase of the polyphase electrical system, and in which the controller is operable in addition to adjust the operation of the utility company's meter to effect a compensation for the cross-phase error. 4

8. The arrangement according to claim 47, characterized in that the controller is also operable to effect the compensation for the cross-phase error by causing the means to receive the digital measurement signals and generate measured data, - 91 - generate data of watts by multiplying the samples of the digital signal of measurement of current of the first phase by the samples of the digital signal of measurement of voltage of the second phase and by multiplying the samples of the digital signal of measurement of voltage of the first phase by the samples of the digital signal of the current measurement of the second phase. 4

9. The array according to claim 41, characterized in that the controller is further operable to perform one or more diagnostic tests using the measured data to determine if a current polarity error is present, and in which the controller is operable further. to adjust the operation of the utility company meter to effect a compensation for the current polarity error. 50. The arrangement according to claim 49, characterized in that the controller is operable to effect compensation for the current polarity error by causing the means for receiving the digital measurement signals and generating measured data to multiply the measurement samples of Current voltage corresponding to at least one phase of the polyphase electrical system per -1. 51. The array according to claim 41, characterized in that the controller is also operable to perform one or more diagnostic tests using the measured data to determine if a lost voltage error is present, and in which the controller is Also operable to adjust the operation of the utility company meter to effect a compensation for the lost voltage error. 52. An arrangement for use in an electric utility meter, the electric company meter is operable to be connected to one or more types of electric service, the arrangement is operable to detect and compensate for a wiring error, the arrangement is characterized because it comprises: a) a conversion circuit to generate a measurement of energy consumption and to generate measured data, the measured data include magnitude and phase angle data of voltage and magnitude angles and current phase angle for a plurality of phases in a polyphase electrical system; b) a memory; and c) a controller operably connected to the memory and to the conversion circuit, the processor is operable to receive measured data of a plurality of phases in a polyphase electrical system, to identify a type of electric service present based on the measured data; and t - 93 - performing one or more diagnostic tests using at least a portion of the measured data and the type of electrical service present to determine if a wiring error is present and to identify the wiring error of a plurality of wiring errors if a wiring error is detected. 53. The arrangement according to claim 52, characterized in that the controller is 10 operable in addition to: automatically adjust the operation of the electric utility meter to effect a compensation for the identified wiring error, the compensation increases the accuracy of the energy consumption measurement 15 of the electricity company's meter. 54. The arrangement according to claim 52, characterized in that it comprises a screen connected to the controller for displaying information that provides an indication corresponding to the error of 20 identified wiring. 55. The arrangement according to claim 52, characterized in that the controller is further operable to periodically perform one or more diagnostic tests using the data measured for To determine if a polarity error of -94-voltage is present, the voltage polarity error comprises at least one phase voltage which is approximately 180 ° out of phase, and in which the controller is further operable to adjust the operation of the electricity company's meter and make a compensation for the voltage polarity error. 56. The array according to claim 52, characterized in that the controller is further operable to perform one or more diagnostic tests using the measured data to determine if a cross phase error is present, and in which the controller is operable in addition to adjust the operation of the utility company's meter to effect a compensation for the cross-phase error. 57. The array according to claim 52, characterized in that the controller is further operable to perform one or more diagnostic tests using the measured data to determine if a current polarity error is present, and in which the controller is operable further. to adjust the operation of the utility company meter to effect a compensation for the current polarity error. 58. The array according to claim 52, characterized in that the controller is further operable to perform one or more diagnostic tests - 95 - using the measured data to determine if a lost voltage error is present, and in which the controller is Also operable to adjust the operation of the utility company meter to effect a compensation for the lost voltage error. 59. The arrangement according to claim 52, characterized in that the controller is also operable to periodically perform one or more diagnostic tests when obtaining expected values from the memory and when comparing the measured data with the expected values.