QUANTIFYING ISOLATION VALVE LEAKAGE

Abstract: Valve leakage is quantified by measuring a variable that is commensurate with a heat transfer characteristic of the pipe wall (30) and comparing the measurements to data stored in a database (84) which embodies a quantitative relationship between an index commensurate with the heat transfer characteristic variable and a range of valve leakage rates that could occur for the given value. In a straight forward implementation of the invention, a thermal hydraulic analysis of the specific valve and associated piping are performed a priori to establish a database of pipe wall temperature downstream of the valve as a function of steam flow rate. The wall temperature is simply measured and compared with the database. In another embodiement, an air cooled sleeve (54) is installed around the pipe (48) downstream of the valve (50) and a controlled flow of air is passed through the annulus (62) between the pipe and the sleeve. The temperature rise of the flowing air is measured and is used to compute the flow rate of steam leaking through the valve. In yet another embodiment, the valve leakage is quantified by monitoring and controlling heat input into a local section of a horizontal pipe (94) upstream of the valve. The center zone (106) of the heaters (96) is controlled to raise the pipe temperature a certain amount above the steam temperature and the power required to maintain the temperature is measured. The database provides a quantitative relationship between such power input and stream flow through the valve.

Description: QUANTIFYING ISOLATION VALVE LEAKAGE Background of the Invention The present invention relates to piping systems and associated valves, and more particularly, to a method and apparatus for quantifying the leakage through an isolation valve. Recent investigations into the loss or deterioration of heat rates in nuclear and fossil power plants indicates that nearly half of such loss is attributable to incomplete plant cycle isolation. As a practical matter, such degradation is a result of leaking isolation valves dumping high pressure steam to the plant condenser. Some effort has been made to identify the sources and magnitudes of isolation valve leaks, but known techniques are unreliable and are not adapted for providing detailed information suitable for setting up a comprehensive plant maintenance and improvement program. One known technique momentarily locates a sensor downstream of a valve, and the acoustic emissions occurring due to leaking steam are analyzed to characterize valve leakage as small, medium, or large, without further quantification. A major problem with this type of technique is the significant extent of background noise. In an even more informal technique, an experienced site engineer may use a stethoscope to listen for valve leakage, and feel the pipe and pipe hangers downstream of the valve to detect a rise in temperature. In this seat of the pants approach, the result is a qualified guess as to whether the valve leakage is small, medium, or large. Summary of the Invention It is thus an object of the present invention to provide a method and apparatus for quantifying the leakage through an isolation valve or the like. It is a further object of the invention, to provide such quantification in a manner that can easily be repeated at intervals selected by the operator. It is a more particular object to enable such operator to easily make a plurality of measurements throughout the plant on a consistent basis, so that the resulting data may be utilized in a plant maintenance and planning program. It is a further object that the method and apparatus provide a real time display or record of the leak rate, which can be observed by the technician who is making the measurement at the location of the valve or associated piping, and optionally, for further use in a central computing or planning station. In accordance with the invention, valve leakage is quantified by measuring a variable that is commensurate with a heat transfer characteristic of the pipe wall and comparing the measurements to data stored in a database which embodies a quantitative relationship between an index commensurate with the heat transfer characteristic variable and a range of valve leakage rates that could occur for the given valve. In a straight forward implementation of the invention, a thermal hydraulic analysis of the specific valve and associated piping are performed a priori to establish a data base of pipe wall temperature downstream of the valve as a function of steam flow rate. The wall temperature is simply measured and compared with the data base. In another embodiment, an air cooled sleeve is installed around the pipe downstream of the valve and a controlled flow of air is passed through the annulus between the pipe and the sleeve. The temperature rise of the flowing air is measured and is used to compute the flow rate of steam leaking through the valve. In yet another embodiment, the valve leakage is quantified by monitoring and controlling heat input into a local section of a horizontal pipe upstream of the valve. The center zone of the heaters is controlled to raise the pipe temperature a certain amount above the steam temperature and the power required to maintain the power is measured. .The database provides a quantitative relationship between such power input and steam flow through the valve. Brief Description of the Drawings These and other objects and advantages of the invention will be described below with reference to the accompanying figures, in which: Figure 1 is a schematic of a portion of the piping system associated with isolation valves for an industrial process; Figure 2 is a section view taken along line 2-2 of Figure 1, showing the first embodiment of the invention; Figure 3 is an enlarged detail view taken along line 3-3 of Figure 2; Figure 4 is a graphic representation of the dependence of pipe wall temperature downstream of a typical isolation valve, for various leakage rates; Figure 5 is a top view, in part longitudinal section, showing the second embodiment of the invention; Figure 6 is a section view taken along line 5-5 of Figure 5; Figure 7 is a cross section view a pipe associated with an isolation valve, including strip heaters for implementing the third embodiment of the invention; Figure 8 is a schematic of the heat generation and temperature measurement components associated with the third embodiment of the invention; Figure 9 is a schematic variation of the:third embodiment of the invention shown in Figure 8; and Figure 10 is a section view of the pipe and associated heater arrangement of the embodiment shown in Figure 9. Description of the Preferred Embodiments Figure 1 shows a portion 10 of an industrial process in which the fluid in the process is isolated from other portions of the system, by one or more isolation valves 12, 14. In the illustrated portion 10 of the system, an upstream pipe 16 contains fluid at a temperature and pressure defined by the operation of, for example, a steam generator in a nuclear or fossil power plant. The downstream pipe 18 connects the valve 12 to a bypass line 20, which for example, may lead to a condenser portion of the power plant (not shown) . Similarly, upstream line 22 is exposed to a given process condition and downstream pipe 24 is exposed to the bypass condition in line 20. Pipes 18 and 24 may be connected to the bypass line 20 through check valves 26, 28. In order to maintain maximum efficiency, i.e., heat rate in the process cycle to which pipes 16 and 22 are connected, isolation valves 12, 14, and other such valves that may be connected to the process, should not leak. Flow through valves 12, 14 should occur only when necessitated or desired for safety or other purposes, but typically not during nominal operating conditions. Figures 2 and 3 illustrate one embodiment of the present invention wherein the leak rate, for example through valve 12, can be quantified. Typically, pipe 18 has a thick layer of insulation 30 in intifnate contact therewith. In accordance with the present invention, a plurality, typically four, temperature sensors such as 32, 34, 36, 38, are supported on the outer surface of the pipe 18, beneath the insulation 30. In the particular embodiment shown in Figures 2 and 3, the thermocouples 32, 34, 46, and 38 are space apart 90° from each other and are held in place by a circumferentially extending stainless steel band 42 having straps 44 or the like for supporting the cable and associated leads which, more conveniently, are gathered together and terminate outside the insulation at one or more connectors 40. A screw clamp 46 or the like can be used to tighten the steel band 42 around the outer diameter wall or surface of the pipe 18. The quantification of the leak rate in accordance with the present invention is based on measuring a thermal variable on the pipe that is associated with the isolation valve, such as temperature, and computing the leak rate from a quantitative relation between the measured thermal variable and the rate of fluid leakage through the valve at a given process condition. Typically, the quantitative relation would be in the form of a database or a functional relationship that is established a priori for the particular sizes and material composition of the upstream pipe 16, valve 12, downstream pipe 18 and bypass line 20, and the fluid properties and conditions associated with the process cycle to which line 16 is exposed. Typically, pipe 16 is connected to a main steam line of a nuclear or fossil power plant, or a steam supply line for some other industrial process. Figure 4 is a graphic illustration of a relationship determined analytically between the outside wall temperature of the downstream pipe 18, as a function of distance from the bypass valve •12, for isolating valve leak rates varying from 0 to 1% of throttled flow, at operating conditions of the system as manifested in line 16. It can be seen that, at a distance of five feet (60 inches) from the valve outlet, the outside temperature of the pipe if no leakage occurs, is approximately 165° F, whereas at the same pipe location and an assumed 1% leakage rate, the wall temperature increases to about 450° F. This extent of outside wall temperature dependence on leak rate is sufficient to support a reasonably accurate determination of leak rate from a wall temperature or equivalent measurement. In the embodiment of the invention shown in Figures 2 and 3, the band of thermocouples 32, 34, 36, and 38 will thus preferably be located approximately 60 inches from isolation valve 12, based on the predicted temperature dependence shown in Figure 4. Generally, before the thermocouples are installed, the piping arrangement such as shown in Figure 1 is inspected and preferably photographed, the material types and properties, and the condition of the insulation noted, and the results entered into a computer program or the like which is adapted to perform thermal hydraulic analyses of piping systems. Such programs could include ANSYS, which is widely available to utilities in the United States, or its equivalent. For each valve 12 and associated piping 16, 18, over a variety of steady state process conditions in upstream pipe 16, a database, or a functional relation, of the quantitative relation between an index commensurate with the heat transfer characteristic of the downstream pipe wall, and a range of valve leak rates that could occur when the upstream pipe 16 is exposed tα the process condition, is established. In effect, data equivalent to plots such as shown in Figure 4, are prepared for each valve 12 at one or more assumed or known process conditions. From the data from each valve as shown in Figure 4, the number of thermocouple bands 42 and their axial position along the pipe 18 from the valve 12, will be selected on the basis of maximizing the difference in expected temperature or other measured thermal property between zero and the maximum assumed leakage, while avoiding anomalies or interferences resulting from the peculiarities of the piping or other environmental factors associated with each valve. These data can be provided under the assumption that either the insulation will be in place, or will be removed during the measurement. Preferably, the thermocouples 32, 34, 36, 38 are essentially permanently mounted on the pipe 18 and covered with insulation 30 as shown in Figure 2, with only the connectors 40 exposed near the surface of the insulation. Whenever the plant operator decides to perform a leak test, a cart with test equipment, to be more fully described below, can be wheeled to the location of the thermocouples and the connectors 40 can be plugged into the test station. The operator then assures that the process conditions in the upstream piping 16 and the other conditions associated with the piping system are within the tolerances or envelopes of the database that was previously prepared. The temperatures are measured and the resulting inferred leak rate can be displayed to the technician and recorded on paper or on computer media for input into a master plant maintenance program from which similar data from other valves 14 are accumulated and- processed to determine plant optimization decisions. For example, using computer programs such as Pepse, Orcent-II or Therm, which are commonly available, the valve leakages having the greatest impact on plant heat rate can be identified and given higher priority for repair during the next outage. Similarly, after a pattern of"leakages and time periods between repair and subsequent leakage develops, a planned maintenance program can be established to minimize the adverse impact of isolation valve leakage over the long term operation of the plant. Figures 5 and 6 show another embodiment of the invention wherein the downstream pipe 48 near isolation valve 50, has the normal insulation 52, such as hydrous calcium silicate removed and replaced with a measurement sleeve 54. The sleeve 54 includes a pipe 56 defining a cylinder, and end closures 58, 60 which thereby define a sealed annular space 62 between the cylinder 56 and the pipe outer surface 48. A strapped on insulting blanket 64 is wrapped around the cylinder 56. A measuring station 66, preferably portable, is independently relocatable relative to the measurement sleeve 54 and can be wheeled adjacent to the sleeve 54 whenever a leakage test is to be performed. The measurement station 66 typically includes a tank 68 of air and associated compressor 70, which supplies cold air through inlet line 72 and inlet nozzle 74, to annulus 62. The air is discharged through outlet nozzle 76, into outlet line 80, 82 which passes the air to thermocouple 78. The thermocouple is connected to a computer and printer 84 at the measurement station 66. A thermocouple 86 connected to the inlet line 72 senses the temperature of the air delivered to the annulus 62, and the flow rate is regulated and metered through devices 88, 90. As shown in Figure 6, the cylinder 56 preferably has a plurality of spacers 92 projecting radially inwardly, to maintain a substantially uniform annulus 62. The sleeve arrangement 54 is thus relatively easy to install on a permanent basis and the measurement station 66 can easily be located and plugged in to produce a steady state flow of air through space 62 and make the required measurements. In this embodiment, which may be preferred for use in locations such as main steam isolation valves, a controlled flow of cool air is delivered to the annulus. The temperature rise of the flowing air will be a function of the leaking steam flow from the isolation valve 50. As with the embodiment illustrated in Figures 1 - 4, the functional or other quantitative relation between temperature rise of the air in the annulus and the leaking steam flow. can be predicted analytically or determined experimentally a priori. Figures 7 and 8 show a third embodiment of the invention whereby the valve leakage is quantified by monitoring and controlling heat input to a local section of a horizontal pipe 94 upstream an isolation valve. Figure 7 shows a cross section of pipe 94, and a plurality of heater strips or segments oriented longitudinally on the pipe surface. For convenient reference, heater strip 96 will be referred to as the left outer heater, 98 as the left inner heater, 100 as the right inner heater, and 102 as the right outer heater. As shown in Figure 8a, the outer heaters 96, 102 include a single heating element 104, and the inner heaters 98, 100, have 4 compound heating elements consisting of a center region 106 and independent peripheral regions 108, 110. The heater strips 96, 98, 100, 102 are in closely spaced, parallel relation, which provides exposure of the underlying outer surface of pipe 94, for the mounting of a plurality of thermocouples 112, 114. In the illustrated embodiment, thermocouple #'s 1, 2, 3, 4, and 5 define an orthogonal set 112, centered about thermocouple # 1, so that #'s 3 and 5 define an x axis and #'s 2 and 4 define a y axis. Optionally, the set of thermocouples 114 are located at diagonal corner positions as indicated by f's 6, 7, 8 and 9. These thermocouples 112 and central heating region 106 define a first, inner control zone 116 within which the surface temperature of the pipe 94 is to be maintained at a substantially constant, predetermined temperature. The envelope defined by the extremities of the heating elements 104, 108, define a second, outer control zone 118. Leads associated with each heater pass through respective flexible conduits 120 to a junction box 122 which is substantially permanently mounted on the piping 94. Similarly, the leads 124 associated with the thermocouples 112, 114, are connected at 126 to the junction box 122. In a manner similar to that described with respect to the second embodiment shown in Figure 5, a portable control panel 130 (Figure 8b) can be placed on a cart (not shown) and wheeled to the location of the junction box 122 when a leakage measurement is to be made. Heater leads 134 associated with outer heaters 96, 102, and heater leads 136 associated with inner heaters 98, 100 are selectively connectable such as at 128 to the junction box, and a multi-conductor wire 132 is likewise connectable between the control panel 130 and the junction box 122. In the illustrated embodiment, the temperature of the pipe wall within region 116 is maintained at a constant 500° F for example, by controlling the heaters so that the temperatures of the thermocouples 112 indicate 500° F. The heaters are arranged and controlled such that the heat generated within control zone 116 flows only radially relative to the pipe 94, because the heat generated between region 118 and 116 maintains a substantially steady state heat balance along the x and y axes at the boundary of region 116. The heaters are wired such that a watt meter 138 is connected through lines 140, 142 to the central heater regions 106. Temperature controller 148 is connected to heater regions 106 via lines 144, 146 through the watt meter 148, and is responsive to the output of thermocouple # 1 through signal line 150. A second temperature controller 152 controls heating elements 108 and 110, on heaters 98, 100, through signal lines 154, 156, and 158. Similarly, a third temperature controller 160 controls the output of heater elements 104 on heaters 96, 102, via lines 162, 164 and 166. Lines 158 and 160 are responsive to the thermocouple outputs for thermocouple # , s 2 and 3, respectively, and thus the signals on lines 150, 158, and 166 provide a feedback so that the heaters can be adjusted in accordance with the measured temperature. A. data logger 168 receives the thermocouple readings from multi-conductor 132, and the watt meter output via line 170. A portable computer, such as an IBM XT 172 interacts with the data logger 168 and with a printer 174 for recording the data. The computer can have a monitor (not shown) for displaying to the technician the thermocouple readings, watt meter output, and calculated leakage rate, while the test is being performed. In addition, the computer can record the data on computer media such as a diskette or the like, which may in turn be combined with similar data from readings taken from other valves throughout the plant. It should be appreciated that the first embodiment of the invention is the easiest to implement, and preferably would be used if circumstances permit, i.e., if the temperature profile of the downstream pipe has a strong dependence on leak rate, and a sufficient straight length of pipe immediately downstream of the valve is available for mounting the sensors. In practice, however, in many power plants an insufficient straight length of pipe is available such that accurate modeling and proper spacing for the sensors is very difficult. Moreover, depending upon the steam conditions, it may be difficult to properly account for heat losses through the valve itself. An additional complication arises when the fluid downstream of the valve cannot be characterized as fully developed turbulent flow. In such circumstances, i.e., where the steam is of a relatively low quality or has experienced substantial condensation, the heat transfer coefficient from the fluid to the pipe walls approaches a comparatively insulating character, i.e., condensing film or boiling film regime. These conditions result in very little variation in pipe wall temperature with variations in leak rate. Thus, the first embodiment of the invention is suitable for use in a straight, horizontal run of dry steam that is characterized by fully developed turbulence. If the first embodiment is to be implemented downstream of the valve, care must be taken in properly modeling the heat losses through the valve. A variation of the first embodiment can be implemented even if some of the foregoing limitations are relaxed, if a sufficiently long straight run of pipe is available downstream of the valve. In this instance, sensors can be located at a plurality of axial positions and the leak rates correlated to the temperature profile in a manner that is not as sensitive to the proper determination of absolute heat losses through, for example, the valve. The second embodiment of the invention is somewhat more complicated than the first embodiment, but provides greater accuracy and therefore is preferable for use at critical locations in the plant, where sufficient room is available downstream of the isolation valve. In many circumstances, however, there will be insufficient length of straight pipe runs downstream of the valve, or the fluid conditions within the pipe deviate from fully developed turbulent flow, so that measuring the pipe wall temperature, or the heat rate through the pipe wall, will provide insufficient dependence on leak rate and therefore not provide satisfactory results. Under these circumstances, the third embodiment of the invention is preferred. Ideally, the third embodiment is implemented .on a horizontal pipe run upstream of the valve, with sufficient heat applied to the upper surface of the pipe, to maintain the surface temperature of the pipe above the steam temperature in the pipe, preferably by a margin ©f at least 25, and preferably 50° F. Typically, the upstream pipe, particularly under relative low leakage conditions, contains steam in a semi-stagnant condition. Due to the inevitability of some moisture entrained in the steam even as it exits the steam generator, slight condensation of the steam along the main steam line, and a further condensation likely in the semi-stagnant fluid in the pipe upstream of the isolation valve, it is likely that some condensation has occurred in the pipe. This condensation is likely to be at the lower portion of the pipe. Moreover, the heating of the upper pipe surface drives away any condensation and prevents a boiling film condition on the corresponding inner pipe surface. Thus, with the third embodiment of the invention, conditions are established in the pipe which justify the analytical prediction of the behavior of a thermal variable associated with the pipe surface, using the Dittus-Boelter film coefficient for fully developed turbulent flow, in a portion of the pipe that would otherwise not provide suitable conditions for the use of such film coefficient. Under fully developed turbulent flow the inside film coefficient varies with the steam flow rate. Therefore the thermal resistance of the film varies with the steam velocity. By utilizing an external heat source and temperature controller it is feasible to control the outside pipe temperature at a specific selected value. The heat required to maintain a constant outside pipe temperature will increase as the steam velocity increases. It is therefore feasible to analytically and/or experimentally establish a relationship between heat input (watts) and steam flow rate (lbs/hr) for a given pipe size. The stored database or functional relation between an index and the leak rate are preferably based on the equations for calculating the thermal resistances and heat transmission as a function of steam velocity as set forth in the Appendix hereto. A variation of the third embodiment of the invention is shown as a schematic 180 in Figures 9 and 10. The variation of the invention as shown in Figures 9 and 10 will be described with reference to implementation on a typical 14 inch pipe 94 found in nuclear and fossil power plants. Two band heater 182,184, such as the type available as Watlow code number B14A1JP218911V12W328 are located side-by-side circumferentially along the upper surface of pipe 94, with a gap 188 of about 0.11 inch therebetween. Each heater 182,184 has a total length 192 of approximately 12.375 inches, with a heated length 194 of about 11.125 inches and width of 1.5 inches. Five thermocouples 190, indicated by #'s 1-5, are located in the gap 188, with thermocouple #1 centered therein. The terminals 196 of the band heaters are connected via lines 198 in series with ammeter 200 and a variable voltage power supply 202. A volt meter 204 is connected in parallel to the power supply 202, and the power supply 202 is connected to a temperature controller 206 having a line 208 for receiving a temperature sensor signal from, for example, thermocouple #1. It should be appreciated that the schematic of Figure 9 shows wiring for only one thermocouple, #1. Thermocouples #2 and #3, and #4 and #5, can be coupled to respective current, voltage, and control devices, for redundancy or mere monitoring. The arrangement shown in Figure 9 maintains a strip of the outer surface of the pipe 94 at target temperature, for example 50° of above the steam temperature within the pipe, in a manner which permits determination of the power required to maintain such temperatures. As described above in connection with Figures 7 and 8, such data are compared with either analytical or empirical data to infer the leak rate in the valve that is situated in the same pipe run as is the instrumentation 180. I has been found that for a given size and type of pipe, experimental results are repeatable and are, in effect, pffset from theoretical calculations such that satisfactory leak rate measuments can be made from comparison with the calibrated data base. Due to the complex piping arrangement in nuclear and most fossil plants, the instrumentation 180 would be installed upstream of an isolation valve, where long vertical or horizontal runs of piping exists without the presence of other valves, elbows, etc. Thus, it may be appreciated that, depending upon the particular conditions that prevail for a given isolation valve and its associated upstream and downstream piping, one of the three described embodiments, or their equivalents, would be preferred. In general, all three embodiments rely on three steps or components. First, a sensor is provided for measuring a thermal variable indicative of the heat transfer through the pipe. This thermal variable could be the pipe surface temperature (first embodiment) , the power loss through a predefined surface area of the pipe (second embodiment) , or the external power delivered to a predetermined portion of the pipe to maintain the pipe surface at a given temperature (third embodiment) . An index signal is generated, which is commensurate with the measurement of the thermal variable. For example, the index could be an absolute temperature as determined from the voltage generated by the thermocouples (first embodiment) , a temperature change as determined from the thermocouple voltages (second embodiment) , or a power determined from the watt meter (third embodiment) . Finally, the index signal is used as an independent variable or equivalent, to obtain an output signal indicative of the fluid leak rate. The quantitative relationship between leak rate and the index signal can be in the form of a database look-up table, a mathematical correlation, a function, or other analogous dependence. In one embodiment, a look-up table for each valve can be prepared a priori and stored in the computer of a work station that is connected to the sensors when a test is to be performed on the given valve. In another embodiment, a particular functional form of the relationship between leak rate and index signals is stored in the computer, and constants indicative of specific valve characteristics are set by the operator as he performs a test on each valve. The choice depends in part upon the type of modeling technique, the number of nodes and the computing power required to perform the calculation, the extent of central administrative control and quality assurance tracking, and the desirability of the plant operator or technician to make adjustments to the analytical model. APP»ENDIX UJ q = A (To-T . where: q - Heat transmitted from strip heater to pipe (BTU/hr) U - Overall heat transfer coefficient (BTU/hr-ft 2 ) A - Area of pipe where heat nput 1s controlled radially Into pipe wall - ft To - Temperature of O.D. of pipe - °F Ti - Temperature of steam - °F (assumed to be saturation temperature corresponding to pressure) where: U - Overall heat transfer coefficient (BTU/hr-ft 2 ) R2 - Outside radius of pipe - ft R1 - Inside radius of pipe - ft kl - Conductivity of pipe wall - BTU/hr-ft-°F hi - Inside film coefficient - BTU/hr-ft 2 -°F where: *h1 - Inside f lm coefficient (Dlttus-Boelter) - BTU/hr-ft 2 D - Inside pipe diameter (ft) kb - Thermal conductivity of steam, evaluated at the bulk temperature (BTU/hr-ft- F) G - Mass velocity (lb/hr-ft 2 ) V b - Viscosity of steam (lb/hr-ft) evaluated at the bulk temperature Cp - Specific heat at constant pressure (BTU/lb-°F) 0G\- Reynolds number (dimenslonless) Prandtl number (dimenslonless)

Claims: CLAIMS 1. A method for quantifying fluid leakage through a nominally closed isolation valve located in a fluid flow line between an .upstream connecting pipe exposed to a process condition and a downstream connecting pipe exposed to a bypass condition, comprising the steps of: storing a database of a quantitative relationship between an index that varies with the heat transfer rate through the wall of one connecting pipe, and a range of valve leak rates that could occur when the upstream connecting pipe is exposed to the process condition; measuring at a selected position on said one connecting pipe, a variable indicative of the heat transfer through said one connecting pipe at said selected position; from the measured variable, generating an index signal commensurate with said heat transfer rate at said one connecting pipe wall when the upstream connecting pipe is exposed to the process condition; and comparing said index signal with said database and generating from the comparison, an output signal indicative of the fluid leak rate through the valve. 2. The method of claim 1, wherein the index is the pipe wall temperature. 3. The method of claim 1,. wherein the step of storing a database includes storing the relationship between said index and a range of leak rates, for a range of steady state process conditions and bypass conditions. 4. The method of claim 1, wherein the step of measuring said variable includes, mounting a plurality of temperature sensors on the downstream pipe wall at a preselected axial distance from the valve and generating sensor signals commensurate with the changes in the wall temperature, the step of generating an index includes generating a signal indicative of the temperature of the wall, and the step of comparing is performed when the process condition, bypass condition, and temperature index reach a steady state. 5. The method of claim 1, further including the steps of fitting a sealed sleeve around a selected portion of the downstream pipe, introducing a flow of cooling fluid through the sleeve, and locating a sensor responsive to said heat transfer rate on the pipe wall within the sleeve. 6. The method of claim 1, wherein the step of storing a database includes the steps of, analytically modelling the upstream pipe, valve, and downstream pipe including insulation, computing the axial temperature profile of the downstream pipe as a function of leak rate for at least one process condition, selecting at least one axial location on the downstream pipe wall at which the wall temperature will be measured, and wherein the step of measuring a variable includes mounting a plurality of temperature sensors at one or more of said axial locations and the step of comparing is performed during a period of time when the process condition, bypass condition and temperature are in a steady state. 7. The method of claim 1, further including the step of introducing a measured flow of heat onto the wall outer surface of said one connecting pipe at said selected position to maintain the said surface at a constant temperature, and wherein said index is the heat transfer rate required to maintain said surface at the constant preselected temperature. 8. The method of claim 7, wherein the step of introducing heat includes securing a plurality of heater strips in closely spaced relation on the pipe wall outer surface, mounting a plurality of thermocouples in the spaces between the heater strips, and controlling the heater strips in response to the temperatures indicated by at least some of the thermocouples. 9. A method for quantifying fluid leakage through a nominally closed isolation valve located in a fluid flow line between an upstream pipe exposed to a process condition and a downstream pipe exposed to a bypass condition, comprising the steps of: storing a database of a quantitative relationship between an index commensurate with a heat transfer characteristic of the upstream pipe wall, and a range of valve leak rates that could occur when the upstream pipe is exposed to the process condition; generating a signal commensurate with said heat transfer characteristic of the upstream pipe wall when the upstream pipe is exposed to the process condition; and comparing said signal with said database; and generating from the comparison, an output signal indicative of the fluid leak rate through the valve. 10. The method of claim 9, wherein the index is the pipe wall temperature. 11. The method of claim 9, wherein the step of storing a database includes storing the relationship between said index and a range of leak rates, for a range of steady state process conditions and bypass conditions. 12. The method of claim 9, wherein the step of generating a signal includes, mounting a plurality of temperature sensors on the downstream pipe wall at a preselected axial distance from the valve, and monitoring the temperature sensors, and wherein the step of comparing is performed when the process condition, bypass condition, and temperature sensors reach a steady state. 13. The method of claim 9, further including the steps of fitting a sealed sleeve around a selected portion of the downstream pipe introducing a flow of cooling fluid through the sleeve, and locating a sensor responsive to said heat transfer characteristic on the pipe wall within the sleeve. 14. The method of claim 9, wherein the step of storing a database includes the steps of, analytically modelling the upstream pipe, valve, and downstream pipe including insulation, computing the axial temperature profile of the downstream -ipe as a function of leak rate for at least one process condition, selecting at least one axial location on the upstream pipe wall at which the wall temperature will be measured and, wherein the step of generating a signal includes mounting a plurality of temperature sensors at one or more of said axial locations and monitoring the temperature during a period of time when the process condition, bypass condition and temperature are in a steady state. 15. The method of claim 9, further including the step of introducing a measured amount of heat onto a selected surface of the downstream pipe to maintain the surface at a constant temperature, and wherein the heat transfer characteristic is the heat required to maintain the surface at a constant preselected temperature. 16. The method of claim 15, wherein the step of introducing heat includes securing a plurality of heater strips in closely spaced relation on the pipe wall, mounting a plurality of thermocouples in the spaces, and controlling the heater strips in response to the temperature indicated by at least some of the thermocouples. 17. A system for measuring the leak rate through an isolation valve connected between an upstream pipe exposed to a process condition and a downstream pipe exposed to a bypass condition, comprising: means for defining a quantitative relation between a heat transfer index associated with the outer wall of one of said pipes and the rate of fluid leakage through the valve at a given process condition; means secured to the wall of said one pipe for measuring a thermal variable on said pipe; means for generating a heat transfer signal commensurate with the measured thermal variable; processor means responsive to the index signal and coupled to the means for defining a quantitative relation, for computing the leak rate from said quantitative relation; and means for recording the computed leak rate. 18. The system of claim 17, wherein said index is the temperature of the pipe exterior wall surface. 19. The system of claim 17, wherein said index is the heat transfer rate through the pipe exterior wall surface. 20. The system of claim 17, wherein said index is the power required to maintain the exterior wall surface at a constant temperature. 21. The system of claim 20, further including power generation means for maintaining a selected surface of said pipe wall at a known constant temperature and means for measuring the power required to maintain the selected surface at said know temperature; 22. The system of claim 20, further including heater means secured to the upper, outer surface of a horizontal run of said one pipe; temperature sensors secured to the outer surface of the pipe adjacent the heater means; heater control means responsive to the temperature sensor means, for maintaining the surface at a substantially constant temperature, wherein said thermal variable is the power absorbed by the pipe from the heater means, and said means for generating an index signal is responsive tot he means for generating a thermal variable. 23. The system of claim 22, wherein the heater means includes a plurality of closely spaced apart heater strips, and the temperature sensors include at least .five thermocouples secured to the pipe surface in he space between the strips. 24. The system of claim 22, wherein the heater means includes two spaced apart inner heater strip each having a central heating region and two peripheral heating regions, the central and peripheral heating regions being independently controllable, two outer heating strips, each located adjacent to a respective one of the inner heating strips and being independently controllable, and the temperature sensors include at least five thermocouples secured to the pipe surface in the space between the strips. 25. The system of claim 24, wherein one temperature sensor is located between the respective central heater regions, each of two sensors is located between a respective opposed peripheral regions of the inner heaters, and two sensors are located between the central region of one inner heater and a respective outer heater.

Inventors: HAYES JAMES K, HAYES, JAMES, K.
Applicants: COMBUSTION ENG, COMBUSTION ENGINEERING, INC.
Application year: 1990
Main classification: G01M3
IPC codes: G01M3