US 20010040446 A1 Abstract An apparatus in accordance with the present invention allows for a determination of the amount and direction of electric power flowing over a particular high-voltage electric power transmission line without proximate access to said transmission line, and further allows for a determination of the amount of electric power being produced by any particular electric power generation plant connected to an electric power transmission grid.
Claims(23) 1. An apparatus for measuring electric potential and magnetic flux density associated with an electric power transmission line, comprising:
a first sensor for outputting a voltage proportional to the net electric potential associated with said transmission line; and a second sensor responsive to a first vector component of the magnetic flux density associated with said transmission line and outputting a voltage proportional to the time rate of change of the net magnetic flux density generated by current flowing through said transmission line. 2. An apparatus as recited in claim 1 a third sensor responsive to a second vector component of the magnetic flux density associated with said transmission line and outputting a voltage proportional to the time rate of change of the net magnetic flux density generated by current flowing through said transmission line. 3. An apparatus as recited in claim 1 4. An apparatus as recited in claim 2 5. An apparatus as recited in claim 4 6. An apparatus as recited in claim 2 7. An apparatus as recited in claim 6 8. An apparatus as recited in claim 2 9. An apparatus as recited in claim 8 10. An apparatus as recited in claim 2 11. An apparatus as recited in claim 10 12. An apparatus as recited in claim 11 13. An apparatus as recited in claim 9 14. An apparatus as recited in claim 13 15. An apparatus as recited in claim 14 16. A method for monitoring the electric power transmission through one or more electric power transmission lines and communicating such electric power transmission information, comprising the steps of:
(a) measuring the electric potential and at least one vector component of the magnetic flux density associated with each said transmission line to generate a data set; (b) transmitting each said data set to a central processing facility; (c) performing a computational analysis on each said data set to determine the amount of current and the direction of current flowing through each said transmission line, and then computing the power associated with each said transmission line; and (d) communicating said power transmission information to an end user. 17. A method as recited in claim 16 a first sensor for outputting a voltage proportional to the net electric potential associated with said transmission line;
a second sensor responsive to a first vector component of the magnetic flux density associated with said transmission line and outputting a voltage proportional to the time rate of change of the net magnetic flux density generated by current flowing through said transmission line; and
a third sensor responsive to a second vector component of the magnetic flux density associated with said transmission line and outputting a voltage proportional to the time rate of change of the net magnetic flux density generated by current flowing through said transmission line.
18. A method as recited in claim 16 19. A method as recited in claim 16 20. A method as recited in claim 17 21. A method as recited in claim 20 correcting each said data set to compensate for predictable errors relating to the geometry of the particular physical arrangement of the conductors of the transmission line; correcting each said data set to compensate for predictable errors relating to the sensors and their interaction with the respective amplification and filtration circuits; calculating the complex coefficients relating the measured magnetic flux density to the current through the conductors of the transmission line as determined by the geometry of the particular physical arrangement of the conductors of the transmission line; solving a set of linear algebraic equations relating the magnetic flux density to the current through the conductors of the transmission line; combining the phase of the measured electric potential with the phase of the measure magnetic flux density to determine the phase angle of the current through the transmission line with respect to the voltage on the transmission line; calculating the power factor on the transmission line; and determining the magnitude and direction of the real and reactive power on the transmission line. 22. A method as recited in claim 16 23. A method as recited in claim 22 Description [0001] The present application claims priority from U.S. provisional application 60/196,720 filed on Apr. 13, 2000 and U.S. provisional application 60/226,130 filed Aug. 18, 2000. This application relates to an apparatus and method for the measurement and monitoring of electric power generation and transmission associated with one or more power generating plants. The entire disclosures contained in U.S. provisional applications 60/196,720 and 60/226,130, including the attachments thereto, are incorporated herein by this reference. [0002] Various apparatus and methods currently exist for measuring and monitoring the amount of electric power generated by any particular electric power generation facility connected to an electric power transmission grid. Common apparatus and methods are also available for measuring and monitoring the amount of electric power flowing over any particular transmission line. Specifically, most electric power plant operators employ a Supervisory Control and Data Acquisition (SCADA) system to monitor their electric power generation and transmission systems. Each substation connected to the transmission grid is equipped with several potential transformers (PT) and current transformers (CT) to measure the voltage, current, and electric power flow on each line and bus. The PT and CT data is monitored in real time and transmitted back to a central computer from each substation through a Remote Terminal Unit (RTU) using various wired and wireless communication methods. Such data is compiled to provide the electric power plant operators with accurate and up-to-date generation and transmission data. [0003] Of course, implementation of these methods requires proximate access to the physical facilities associated with the generation and transmission of electric power. The owner or manager of these physical facilities is able to control or limit proximate access to said facilities, and thus is able to prevent any particular party that employs current technology from directly measuring and monitoring either the amount of electric power flowing over a particular transmission line or the amount of electric power being generated by a particular electric power generation facility. Information about electric transmission line flows and electric power generation facility output is useful and valuable for companies engaged in the business of buying and selling electricity on the open market, and power plant operators currently do not release this information to other participants in the market. [0004] It is thus a paramount object of the present invention to provide an apparatus and method for the measurement and monitoring of electric power generation and transmission associated with a plurality of power generation plants without necessity of proximate access to the physical facilities associated with the generation and transmission of electric power. [0005] It is a further object of the present invention to provide an apparatus and method that is capable of ascertaining both the amount and direction of electric power flowing over transmission lines and the amount of electric power generated by any electric power generation plant connected to those lines without necessity of proximate access to the physical facilities associated with the generation and transmission of electric power. [0006] These and other objects and advantages of the present invention will become apparent upon a reading of the following description. [0007] The present invention is an apparatus and method for the measurement and monitoring of electric power generation and transmission associated with one or more power generating plants. Specifically, the apparatus and method of the present invention allows for a determination of the amount and direction of electric power flowing over a particular high-voltage electric power transmission line, allows for a determination of the real and reactive components of the electric power, and further allows for a determination of the amount of electric power being produced by any particular electric power generation plant connected to an electric power transmission grid. [0008] The apparatus of the present invention is comprised primarily of one or more monitoring devices that collect the information necessary to determine the electric power flow on any particular transmission line being monitored. Specifically, a monitoring device in accordance with the present invention is installed in a fixed location near a high-voltage electric power transmission line. During the installation process, appropriate measurements are made to establish the spatial relationship between the monitoring device and the multiple phase conductors of the transmission line. The monitoring device is primarily comprised of sensing elements responsive to the electric potential and the magnetic flux densities associated with the transmission line, therefore allowing for periodic or continuous measurements of the electric potential and magnetic flux densities associated with the transmission line. [0009] The method of the present invention relates not only to the collection of information, but also the transmission and processing of the collected information. Specifically, the method of the present invention contemplates discreet or continuous data transmissions of collected information from remote monitoring devices, each of which monitors a particular transmission line or lines, to a central processing facility where a computational analysis is conducted to calculate the amount and direction of both real and reactive electric power flowing on each monitored set of transmission lines. The resulting power data can be further analyzed and compiled to determine the net electric power output of any electric power generating facility connected to the monitored transmission lines. [0010]FIG. 1 is a perspective view of a preferred embodiment of the apparatus for the measurement and monitoring of electric power generation and transmission in accordance with the present invention; [0011]FIG. 2 is a plan view of the interior of the first weatherproof housing of the apparatus of FIG. 1, which contains the electric and magnetic field measurement components necessary to carry out the function of the present invention, with the door of the housing in the open position; [0012]FIG. 3 is a block diagram depicting the preferred method for the measurement and monitoring of electric power generation and transmission in accordance with the present invention; [0013]FIG. 4 is a block diagram depicting the preferred method of communicating information associated with the measured electric power generation and transmission in accordance with the present invention; [0014]FIG. 5 is a schematic circuit diagram of a preferred amplification and filtration circuit for the magnetic field measurements associated with the apparatus and method of the present invention; [0015]FIG. 6 is a schematic circuit diagram of a preferred amplification and filtration circuit for the electric potential measurements associated with the apparatus and method of the present invention; [0016]FIG. 7 is a schematic representation of magnetic flux associated with a conductor through which current passes; [0017]FIG. 8 is a schematic representation showing the phasor relationship between the unit phasor components present in an infinitely long, three-phase electric power transmission line; [0018]FIG. 9 is a schematic representation of an exemplary three-phase electric power transmission line geometry with a pair of magnetic field sensors located at ground level for measuring the magnetic flux density associated with the transmission line; [0019]FIG. 10 is a schematic representation of the three conductors of a three-phase electric power transmission line, with an electric potential sensor located a predetermined distance above ground level for measuring the electric potential associated with the transmission line; [0020]FIG. 11 is a schematic representation showing the capacitances resulting from the interaction between the conductors of a three-phase electric power transmission line and an electric potential sensor; [0021]FIG. 12 is a typical circuit diagram explaining the relationship of the capacitances shown in FIG. 11; and [0022]FIG. 13 depicts a common arrangement of electric power transmission lines in which independent parallel circuits are disposed on opposite sides of a supporting tower. [0023] The present invention is an apparatus and method for the measurement and monitoring of electric power generation and transmission associated with one or more electric power generating plants. This is preferably accomplished through measurement and collection of data related to the amount of electric power flowing over one or more transmission lines operably connected to a particular electric power grid and operably connected to said one or more electric power generating plants. Computational analysis of this data allows for a determination of the specific amount of electric power being generated by these electric power plants connected to the transmission and distribution grid. [0024] Electric power is distributed over most public transmission grids in three-phase form, each of said phases being carried over a separate conductor. For purposes of the present application, the term “transmission line” is used to refer to the three separate conductors. Each of these separate phases generates its own time-varying magnetic and electric field. The three phases are out of phase with each other by one third of a cycle, such that the sum of the fields generated by these three phases would essentially be zero if all three phases were transmitted over conductors that were closely packed. The physics of electric power transmission, however, dictates that the three phases maintain physical separation, the distances for which are determined by factors such as line voltage, insulator effectiveness, etc. This physical separation means that the electric and magnetic fields produced by each phase do not completely cancel each other. In accordance with the Biot-Savart Law of Magnetic Fields and Laplace's Equation, any point in space around these three phases will contain an electric potential and a magnetic field that are determined by a known set of factors. These factors include: line voltage, amount of current, direction of current, spatial arrangement of the three conductors with respect to each other and to the measurement point, and the electromagnetic properties of the surrounding environment. [0025] The present invention employs sensors to measure the electric potential and the various vector components of the magnetic field surrounding the transmission lines. For purposes of this description, the equipment which is located remotely but within the general proximity of the transmission lines is referred to as the “monitoring device.” [0026] Referring now to FIG. 1, in the preferred embodiment, the monitoring device [0027]FIG. 2 is a plan view of the sensor unit with the door [0028] Regardless, although not shown in FIG. 2, the output measurement from the conducting plate [0029] Magnetic flux density measurement is accomplished by the use of coils [0030] The voltage across each magnetic field sensor [0031] Of further note, three coils may be utilized to improve accuracy or aid in alignment of the other two coils. The third coil could potentially improve accuracy in situations in which the conductors are sagging significantly. The addition of the third coil would be oriented such that the sensitive axes of the three sensors are mutually perpendicular. Of course, the addition of this third axis of measurement would necessitate modification of the computational analysis to include a third coordinate accordingly. [0032] As further shown in FIG. 2, the output measurements from the magnetic field sensors [0033] Location of the monitoring device [0034]FIG. 3 is a block diagram of the external, field-installed portion of the invention—the monitoring device [0035] Specifically, the preferred monitoring device [0036] The output voltage of the first magnetic field sensor [0037] The input impedances of the amplification and filtration circuits [0038]FIG. 5 depicts preferred amplification and filtration circuits [0039]FIG. 6 depicts a preferred amplification and filtration circuit [0040] After the amplification and filtration of the respective signals as described above, the output voltages are then applied to the inputs of an analog multiplexer (MUX) [0041] Before completing the description of the amplification and filtration circuitry, however, it is noteworthy that in an alternate embodiment, it is contemplated that an apparatus in accordance with the present invention include a sample-and-hold amplifier for the output of each filtered coil sensor. The output voltages of the respective amplification and filtration circuits [0042] From the MUX [0043] The converted data, now in digital form, is stored in the random access memory [0044] Finally, with respect to FIG. 3, the individual electronic components of the monitoring device [0045]FIG. 4 is a block diagram of preferred communication components and the central processing facility of the apparatus and method of the present invention. These components are not installed in the field with the monitoring device [0046] At the central processing facility [0047] As an additional refinement, the communications channel from the microprocessor [0048] Returning to the computational analysis performed at the central processing facility [0049] Specifically, with the data provided from the monitoring device, the magnitude and direction of the electric power flowing through a given transmission line, along with the real and reactive components of that power, can be determined through a computational analysis preferably carried out using a digital computer program. [0050] The horizontal and vertical magnetic field components calculated in the analysis component depend linearly on the line currents, albeit with complex coefficients. That is, the horizontal magnetic field component can be represented by a complex number (a phasor) that is a linear combination of the horizontal magnetic field contributions caused by each of the three conductors of the three-phase transmission line, with the coefficients of combination being complex numbers determined from the geometrical arrangement of the conductors and the sensor location with respect to the conductors. In other words, there results n complex simultaneous linear equations in n complex unknowns with n squared complex coefficients. Such a set of equations is invertible (i.e., it may be solved by a number of means, such by the use of Cramer's Rule or by Gaussian elimination) and is solved analytically. Given perfect measurements (or actual measurements, perfectly corrected) the real and imaginary components of the electric power on the line are determined exactly. [0051] The preferred method of computational analysis has two components. The first component of the computational analysis is run off-line. It consists of computation of the complex coefficients of the above-referenced set of simultaneous linear equations which define the geometrical arrangement of the conductors and the sensor location with respect to the conductors, followed by inversion of the coefficient matrix. These results are stored in a database. This first component of the computational analysis needs to be performed only once for a given installation of a monitoring device with respect to a particular transmission line. [0052] The second component is run on-line. It corrects the measured phase angle for sensor errors and geometrically induced errors to get actual horizontal and vertical magnetic field values, and multiplies the resulting measurement vector by the inverted coefficient matrix referred to above to determine line current and phase angle. In this regard, the sensed phase angle differs from the phase angle on the transmission line in a very complicated way, being affected by: the geometrical relationships between the conductors of the transmission line and the location of the monitoring device in three-dimensional space; sag of the transmission line; and the inherent minor inaccuracies of the sensors and their associated electronics. Nevertheless, many, if not all, of the resulting errors can be calculated and compensated for, leading to a computational estimate of the power factor on the line. Since the phase angle on the transmission line is calculated, and the real and reactive powers are calculated as signed quantities, the direction of flow of both the real and the imaginary components of the apparent power can be determined as well. [0053] Method of Computation [0054] Using the monitoring device [0055] The magnitude of the magnetic field intensity H generated by an infinitely long, straight conductor is governed by the equation:
[0056] where I is the current flowing through the conductor, and r is the distance from the conductor to the point at which the magnetic field intensity is being measured. It is somewhat more common to refer to the strength of a magnetic field in terms of the magnetic flux density B. The magnetic flux density is defined as: B=μ [0057] where μ [0058] which reduces to the simple formula:
[0059] Accordingly, this formula can be used to determine the magnetic flux density B in milligauss at a distance r (measured in meters) from an infinitely thin conductor carrying I Amperes of electrical current. [0060] For example, at a distance of r=50 feet=15.244 meters from a conductor carrying a current of I=100 Amperes, the magnetic flux density is:
[0061] Since H is a spatial vector, B is also a spatial vector. For this reason, the direction of the magnetic flux density B is perpendicular to a line drawn from the measurement point to the nearest point on the conductor. According to the familiar “right-hand rule” for determining direction, if the current is directed toward the viewer, the magnetic flux lines are directed counter-clockwise, giving a magnetic flux density vector B directed as shown in FIG. 7. [0062] Also, as shown in FIG. 7, the angle φ is the angle between r (the line drawn from the measurement point P and the conductor) and the positive x-axis. Since B is perpendicular to r, the spatial vector B can be resolved into its horizontal and vertical components B B B [0063] For a three-phase alternating current (AC) electric power transmission line, there are three conductors, carrying currents that are 120° apart in time phase. The time relationship between the currents may be represented by phasors, as in standard AC circuit analysis. [0064]FIG. 8 is a diagram showing the phasor relationship between the unit phasor components present in an infinitely long, three-phase transmission line over the flat Earth. Mathematically: I I I [0065] where Io is the (signed) RMS amplitude of the current on each conductor, and A, B, and C are unit phasors chosen to be 120° apart, as follows: [0066] The magnetic flux density phasor caused by the phasor current in each conductor may then be calculated by:
[0067] Each of the three magnetic flux densities calculated in equations (14), (15), and (16) has a horizontal and a vertical component. Accordingly, the horizontal and vertical components of the three-phase transmission line, as shown in FIG. 8 and which are analogous to the vector components of a single phase line as per equations (6) and (7) above, may be calculated as follows:
[0068] Referring again to FIG. 8, the x and y coordinates of the three conductors of a three-phase transmission line may be designated as (x [0069] and φ φ φ [0070] The horizontal (x) and vertical (y) spatial components as determined in equations (17) through (22) may be superposed, yielding expressions for the horizontal magnetic flux density (B [0071] Equations (29) and (30) have been derived under the assumption that the current on the first conductor line I [0072] where Io is a scalar element, which may be either positive or negative. In fact, the current on the first conductor may have any phase relationship. Its phase has meaning only with respect to some well-defined phase reference, which will be defined below as the phase of the voltage on the first conductor. In other words, Io is not a scalar, but rather is also a phasor and is hereinafter denoted by Io, where Io=Io ∠φ (32) [0073] Accordingly, equation (31) becomes: I [0074] with Io=|Io| (34) [0075] In this same respect, equations (29) and (30) must be suitably modified as well:
[0076] Some interpretation is now in order. A, B, C, r B B [0077] where
[0078] a [0079] These are linear relationships. Both equations (37) and (38) constitute one equation in one unknown, albeit with a complex given phasor (B [0080] With one linear equation in one unknown, the equation is solvable. Solving for Io from (37) and (38): [0081] The above calculations indicate that, in principle, the phasor Io, in both magnitude and angle, can be determined from a measurement of the horizontal component of the magnetic flux density B [0082] Accordingly, only one measurement—of either B [0083] A Numerical Example [0084]FIG. 9 is an example of a line geometry with a pair of magnetic field sensors φ φ φ [0085] r sin φ sin φ sin φ cos φ cos φ cos φ [0086] Then, substituting into Equations (35) and (36) yields:
[0087] Assuming, [0088] and A, B, and C are as given in equations (11), (12), and (13), we have:
[0089] Since B [0090] The above numerical example predicts that, for the geometry shown in FIG. 9, the magnetic flux density at the origin would have a horizontal component of 22.692 milligauss and a vertical component of 47.299 milligauss. Further, with Io=1000∠0°, we have: B [0091] This result may be interpreted as meaning that the phase of the measured horizontal magnetic flux density (−29.98°) is approximately the same as the phase of the first conductor (0°), with a rather large 29.98° error. However, since the 29.98° error depends only on the geometry of the conductor arrangement, it can be calculated and accounted for. [0092] Referring again to equations (39) and (40): [0093] and
[0094] Accordingly, with the measurements of B [0095] From a measurement of B [0096] which demonstrates the earlier assertion that Io may be determined from either the measurement of B [0097] Another very frequent arrangement used by many utilities is to place two parallel three-phase circuits on a single tower structure. Such a scenario can essentially be handled by the same method, except that both B [0098] Electric Potential Sensor Analysis [0099] The discussion immediately following equation (63) may be thought of as demonstrating that the output voltage of a magnetic field sensor constitutes a remote measurement of both the magnitude and the phase of the current on the first conductor. However, the phase of the current has value only when compared to the phase of the voltage on the line, since the real and reactive power are given by: MW=V MVAR=V [0100] where V [0101]FIG. 10 shows the three conductors of a three-phase electric power transmission line, with an electric potential sensor [0102] The electric potential sensor [0103] Although the geometry is complex, the capacitances involved here may be approximated by use of the standard formula for the capacitance of a parallel plate capacitor, which is:
[0104] where ε [0105] For example, assume that r [0106] or
[0107] Thus, the capacitances involved in FIG. 11 are very small by normal standards, but nevertheless the capacitances are real. [0108] The electric potential sensor [0109] Converted to meters: [0110] Then, assuming A=0.10 square meters, the capacitances shown in FIG. 11 may be estimated:
[0111] In FIG. 12, a traditional circuit diagram of this arrangement is shown, assuming that the capacitance Ci has been chosen to be Ci=0.01 μF. [0112] Therefore, the phasor output voltage of the circuit of FIG. 6 is:
[0113] Thus, the capacitive divider output is a highly attenuated linear combination of the line-to-ground voltages appearing on each of the three phases of the electric power transmission line. [0114] For example, if the line-to-line voltage of the circuit is V [0115] and substitution into equation (90) yields:
[0116] The voltage developed across the capacitor Ci has a magnitude of 55.4 mv, with a phase angle of −8.95°. However, since the voltage in the first conductor was assumed to have a phase angle of 0°, the output voltage of the capacitive divider not only provides a voltage whose magnitude is proportional to the magnitude of the line-to-line voltage on the electric power transmission line, but whose phase is approximately the phase of the voltage on the first conductor, the nearest conductor in this example. The error in measuring the phase of the line-to-ground voltage on the first conductor (−8.95° in this case) is dependent only on the geometry of the line conductor with respect to the monitoring device [0117] Remote Determination of Power Factor On An Electric Power Transmission Line [0118] As described with respect to equation (63), if the current on the first conductor was Io=1000∠0° Amperes, the magnetic field sensor [0119] And, as determined in equation (94), the output voltage of the electric potential sensor [0120] Thus, the output of the electric potential sensor [0121] and the angle H [0122] And, therefore: θ [0123] Thus, from a measurement of H [0124] For example, if H θ [0125] so that the power factor on the line is [0126] and the power per phase is
[0127] so that the total transmission line power is [0128] and the reactive power on the line is
[0129] The algebraic sign of the above quantities if vitally important. For the coordinate system defined in FIGS. [0130] Since the essential objective of the present invention is to determine by remote sensors, the total power output of an electric power generating plant, accurate determination of the direction of the power flow on a line is as important as determination of the magnitude of the power flow. Specifically, it is necessary to distinguish between the electric power coming out of an electric power generation plant and the power going in. [0131] Sensor Blending Generalizations and Alternate Mechanizations [0132] Thus, as fully described above, with an electric potential sensor and at least one magnetic field sensor, it is possible to remotely (i.e., by non-contacting means) determine both the magnitude and direction of the power flow on a three-phase electric power transmission line. With two magnetic field sensors, one measuring the horizontal magnetic flux density B [0133] where w [0134] In this case, the average of the horizontal and vertical measurements provides a more accurate measurement than that provided by either measurement taken alone. [0135] Alternatively, if small magnetic fields produce noisier measurements, the weighting factors can be defined as: [0136] which will have the effect of weighting the data from the strongest magnetic field more heavily than that from the weaker magnetic field. [0137] A more pronounced bias in the direction of the stronger field result is provided by choosing: [0138] In each of the above equations, [0139] as is necessary not to artificially inflate or deflate the estimation of the magnitude of the power flow. [0140] In general, more complex combinations of MW [0141] where “f” is a linear or nonlinear function of six variables. [0142] However, a more important advantage than simple noise reduction accrues from the inclusion of both magnetic field sensors, measuring both horizontal and vertical flux density components. A frequently occurring arrangement in electric power transmission lines is the case of parallel circuits disposed on opposite sides of a single supporting tower, as in FIG. 13. [0143] A parallel analysis to that given here for the single three-phase circuit leads to exactly the same form of conclusion as that presented in equations (37) and (38), except that equations (37) and (38) become [0144] where I [0145] if it is assumed that V [0146] r [0147] Equation (117) may be re-written in vector-matrix form as: B=A I (122) [0148] which is the standard form of a set of simultaneous linear equations in n unknowns: AI=B (123) [0149] Equation (123) may be solved in several ways for I: I=A [0150] or equation (123) may be solved by Gaussian elimination. Of course, in equation (123), I is a 2-vector of complex phasors, B is a 2-vector of complex phasors, and A is a 2×2 matrix of complex co-efficients. [0151] Also, equation (123) may be solved by the use of Cramer's Rule, leading to:
[0152] In other words, the frequently occurring case of two parallel transmission line circuits may be handled with one sensor package containing one electric potential sensor, one horizontal magnetic field sensor, and one vertical magnetic field sensor—with the computational requirement that two equations in two (complex) unknowns with complex coefficients must be solved. Since both Fortran and C++ programming languages provide support for complex data types, this analysis is easily carried out numerically by one of the above three indicated methods. [0153] The foregoing computational analysis thus allows for calculation of the magnitude and direction of the electric power flowing through a given transmission line from data collected by the monitoring device [0154] It will be obvious to those skilled in the art that modifications may be made to the embodiments described above without departing from the spirit and scope of the present invention. Referenced by
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