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    • 专利摘要:
    The disclosure provides a well integrity monitoring tool (150) for a wellbore (101; 201), a method using a nuclear tool (156; 200; 1010) and an electromagnetic tool (EM) (152; 300). 400; 1020), for monitoring the well integrity of a wellbore having a multiple pipe configuration (140), and a well integrity monitoring system (1000). In one example, the method (1100) includes: operating a nuclear tool in the wellbore to perform a nuclear measurement at a depth of the wellbore (1110), operating an EM tool in the borehole for performing an EM measurement at the wellbore depth (1120), determining a plurality of pipe properties of the multiple pipe configuration at the depth using EM measurement (1130), the determination , using the properties of the piping, of a nuclear measurement processed from the nuclear measurement (1140), and the use of the processed nuclear measurement to determine a well material integrity at the depth and the interior of an annular space (180, 182, 184) defined by the multiple pipe configuration (1150).
    公开号:FR3067747A1
    申请号:FR1854138
    申请日:2018-05-17
    公开日:2018-12-21
    发明作者:Yike Hu；Weijun Guo；Burkay Donderici
    申请人:Halliburton Energy Services Inc；
    IPC主号:
    专利说明:

    APPLICATION OF THE MULTI-PHYSICAL PRINCIPLE TO THE ASSESSMENT OF WELL INTEGRITY IN A MULTI-TRAIN CONFIGURATION
    TECHNICAL AREA
    The present application relates, in general, to wells and, more specifically, to the evaluation of the integrity of a well material in a wellbore.
    CONTEXT
    Hydrocarbons, such as oil and gas, are located in underground formations. To obtain oil or gas, various well operations, such as drilling, logging and completion, are performed. During these operations, a cladding is used to provide structural support, control pressures and isolate the water inside a well. Casing is typically used inside the cladding to recover the hydrocarbons from the underground formation and deliver the hydrocarbons to the surface of the well.
    BRIEF DESCRIPTION
    Reference is now made to the following descriptions taken in conjunction with the accompanying drawings, in which:
    Figure 1 illustrates a diagram of a partial sectional elevation view of a wellbore system configured to perform, for example, a training test, sampling or monitoring well integrity in a well drilling ;
    FIG. 2A illustrates a side view of an example of a nuclear tool;
    Figure 2B illustrates a sectional view of the nuclear tool of Figure 2A in a wellbore having a multiple pipe configuration;
    Figure 3 illustrates a diagram of an example of a time domain EM tool used for pipe inspection;
    Figure 4 illustrates a diagram of an example EM tool in the frequency domain used for pipe inspection.
    FIG. 5 illustrates a process diagram of an example workflow of an inversion algorithm for determining the properties of the piping, such as the thickness of the metallic piping;
    FIG. 6 illustrates an example of a map of relationships between the well materials corresponding to a signal change (AS);
    FIG. 7 illustrates another example of a map of relations between well materials which illustrates a dependence of the signal contrast of the nuclear tool on the volumetric fraction of cement inside a primary cement sheath;
    Figure 8 illustrates an example of a multi-physical algorithm workflow for providing volumetric cement information in a multi-pipe configuration;
    Figure 9 illustrates a simulated diagram over an extended length of a wellbore with multiple cement conditions;
    Figure 10 illustrates a block diagram of an exemplary well integrity monitoring system constructed in accordance with the principles disclosed herein; and
    FIG. 11 illustrates a process diagram of an exemplary method of using a nuclear tool and an EM tool for monitoring the well integrity of a wellbore having a multiple pipe configuration.
    DETAILED DESCRIPTION
    Cement is often used between the multiple cladding layers, for structural support, pressure control and fluid isolation. During various well operations, a well operator may place other materials in addition to cement, such as proppants and fillers, within the annular spaces of the well defined by cladding and casing . During these well operations, and also during the dismantling of a well, it is advantageous to know the volumetric information on the cement or other well material of interest located within the defined annular spaces of the well.
    The disclosure provides a well integrity monitoring tool, system and method for determining the integrity of a well. The system, method and tool employ a multi-physical approach to assess the integrity of a well material, such as cement, in a configuration with multiple downhole trains. A multiple train or multiple pipe configuration may include production tubing in place. The integrity or quality of the well material is determined by the volumetric information on the well material within an annular space or annular spaces defined by the multiple pipe configuration. The integrity of the well material can be determined by the density of the well material within an annular space. A well material is a material added or injected into the well, for example by the well operator. The well material includes cement (sometimes called concrete), a spacer, mud, a proppant or other fluids, or a solid material injected into a well during the various stages that include drilling, completion, production and abandonment.
    The multi-physical approach disclosed here includes both nuclear and electromagnetic (EM) technology. For example, the disclosure provides a well integrity monitoring tool that includes both a nuclear tool, such as a nuclear cement assessment tool (NCET), based on gamma-gamma scattering, and an EM tool. , such as an EM pipe inspection tool. The measurements obtained by the EM tool, namely, the EM measurements, provide information relating to the thickness and spacing of the cladding and the metal casing, collectively referred to here as metallic piping. EM measurements can provide, for example, five outputs or properties of piping related to metallic piping: casing thickness, production cladding thickness, distance between casing and cladding, distance between production cladding and intermediate cladding , and relative eccentricity between the casing and the cladding. The measurements obtained by the nuclear tool, namely the nuclear measurements, provide information relating to the density of the well material located in the annular spaces defined by the metallic piping.
    The well integrity monitoring tool may further include an integrity processor, implemented on a computer, which receives the EM and nuclear measurements from the EM tool and the nuclear tool and provides an accurate estimate of the volumetric information about the well material behind the metal pipes, for example, a multi-pipe configuration which has at least two layers of metal pipes which are steel pipes.
    Disclosure, therefore, provides solutions for assessing well integrity in a jacketed hole environment. In particular, the advantageously disclosed tool, system and method save time and money associated with determining well integrity without removing the casing during various well procedures, such as cement correction procedure or the cutting and pulling process at the well abandonment stage. The well integrity monitoring tool disclosed herein can be deployed through various means of transportation, such as steel wire, smooth cable, or coiled tubing.
    Referring now to the figures, Figure 1 illustrates a diagram of a partial sectional elevation view of a wellbore system 100 configured to perform, for example, training test, sampling or monitoring of well integrity in a wellbore 101. The wellbore system 100 includes a wellhead 110, a derrick 112 and a movable block 114 supported by the derrick 112. The wellbore system 100 may further include a controller 116 which directs the operation thereof and includes a processor 117 and a memory 118. The wellbore system 100 further includes a means of transportation 120 (such as a steel rope, a smooth cable, coiled tubing, etc.), a logging unit 130, and a multi-pipe configuration 140. The wellbore system 100 may include a tool on a wired line, such as a probe, which can be lowered. at the bottom of a region of interest d in borehole 101 and then raised at a substantially constant speed. The wired line tool in the wellbore system 100 is a well integrity monitoring tool 150 as disclosed herein which is part of a wired logging operation. The transport means 120 can be used to descend and reassemble the well integrity monitoring tool 150 in the well bore 101 to collect data intended for the evaluation of the integrity of the well material inside. of the multiple pipe configuration 140. The data obtained by the well integrity monitoring tool 150 can be communicated to the surface logging unit 130 for storage, processing and / or analysis. . The logging unit 130 can be provided with electronic equipment 134, including processors for various types of signal processing and information communication. One of the processors can be configured to perform the functions of the integrity calculation device illustrated in Figure 10. The control device 116 can also be used to perform at least some of the functions of the integrity calculation device disclosed here .
    The multiple pipe configuration 140 includes multiple cladding trains which are placed inside the borehole 101 dug to protect and support the production of hydrocarbons to the surface 170. In addition to providing stabilization and preventing the sides of the boreholes 101 from collapsing on themselves, the cladding trains can protect the production of hydrocarbons from external contaminants, such as eg. the separation of freshwater tanks from the fluids that are produced through the cladding. The sheathing of a borehole 101, which is also called pipe laying, includes the descent of a pipe (such as a steel pipe) inside the recently dug part of the borehole 101. The small space between the casing and the untreated sides of the wellbore 101 (generally called an annular space) can be filled with well material to permanently secure the casing in place. The well material can be cement and will be called cement in the following discussion of Figure 1. A cladding pipe can be lowered from a floor of the derrick 112, connected one joint at a time, and pushed into a train cladding that was previously inserted into borehole 101. Cladding is applied when the weight of the cladding train is transferred to cladding supports that are positioned near the top of the new cladding, and can use slides or wires to suspend the new sheathing in the wellbore 101. A suspension of cement can then be pumped into the wellbore 101, which then hardens to permanently fix the casing in place. After the cement has hardened, the lower part of the borehole 101 can be dug and the completion process can continue.
    Sometimes the borehole 101 is dug in several stages. For example, the wellbore 101 can be dug to a certain depth, sheathed and cemented, and then the wellbore 101 is dug to a greater depth, sheathed and cemented again, and so on. Each time the borehole 101 is sheathed, a sheath of a smaller diameter is used. The multiple pipe configuration 140 includes a conductor pipe 141, surface cladding 142, intermediate cladding 144, production cladding 146 and production tubing 148. Conductor pipe 141 is the widest type of cladding, and it is usually about 30 to 42 inches in diameter for offshore wells and 12 to 16 inches in diameter for onshore wells. An annular space (not shown in Figure 1) radially outside the conductor pipe 141 can be filled with cement to prevent drilling fluids from flowing outside the conductor pipe and cause erosion. The surface cladding 142 is the next size in the cladding trains and can be several thousand feet in length. An annular space 180 radially outside the surface cladding 142 can be filled with cement 160a to prevent, for example, hydrocarbon fluids from encroaching on the freshwater areas. Intermediate sheath 144 is the next diameter and can be placed to separate difficult or problem areas, such as areas of high pressure or loss of circulation. An annular space 182 radially outside the intermediate casing 144 can be at least partially filled with cement 160b to, for example, isolate the formations which are liable to collapse and cause a loss of circulation in the wellbore .
    Typically, the last type of cladding train that is placed in the wellbore 101 is the production cladding 146, and therefore represents the smallest diameter cladding train. The production cladding 146 can be placed directly in a production tank. An annular space 184 radially outside the production cladding 146 can be at least partially filled with cement 160c to, for example, stop the migration of hydrocarbons in areas of loss of circulation and to prevent the detachment of formations liable to cause a loss of circulation in the wellbore 101. A production casing 148 can then be lowered into the wellbore 101 to produce hydrocarbons from the production reservoir towards the surface 170 and the derrick 112. A lost column ( not shown) can also be lowered into borehole 101. Although it is similar to other cladding trains, a lost column is not lowered over the entire length of a wellbore but is suspended from it using a lost column suspension device. As with cladding trains, the annular space radially outside a lost column can also be filled or at least partially filled with cement.
    The well integrity monitoring tool 150 employs a multi-physical approach to assess the integrity of the well material within the multi-pipe configuration 140. The well integrity monitoring tool 150 includes a tool EM 152 and a nuclear tool 156 which are shown transported in tandem inside the production cladding 146 by the transport means 120. The EM 152 tool and the nuclear tool 156 can be used to assess the integrity of the cement 160a-c behind the cladding when the well integrity monitoring tool 150 operates inside the production casing 148. The EM tool 152 and the nuclear tool 156 take EM measurements and nuclear measurements, respectively , at various depths in borehole 101. Corresponding EM and nuclear measurements can then be evaluated against relationship maps between well materials to determine integrity cement or volumetric information on another well material. EM tool 152 and nuclear tool 156 may be separate tools which may be designed for the purposes described below, or they may be existing EM and nuclear tools which are normally operated individually for the purpose of EM and nuclear logging inspection. The order of the EM 152 tool and the nuclear tool 156 may vary in different applications. For example, the nuclear tool 156 can be placed above the EM tool 152 during transport. In one example, the EM 152 tool and the nuclear tool 156 are combined within a single tool body by co-locating various components of the tools to provide a single combined integrity monitoring tool. The nuclear tool 156 can be the nuclear tool 200 of FIG. 2A.
    Figure 2A illustrates a side view of an exemplary nuclear tool 200 and Figure 2B illustrates a sectional view of the nuclear tool 200 in a wellbore 201 having a multiple pipe configuration. The nuclear tool 200, such as an NCET, is based on the attenuation of gamma rays and includes a source of omnidirectional gamma rays 210 which emits gamma rays towards the entire circumference of the wellbore 201.
    In the example illustrated, the nuclear tool 200 is a configuration with three detectors. The three detectors, the first detector 220, the second detector 222 and the third detector 224, are placed at a predetermined distance from the gamma ray source 210, and are collimated to detect gamma rays at a certain depth of the wellbore 201 which are diffused from the wellbore 201, the piping inside the wellbore and the well material behind the piping. The nuclear tool 210 includes a barrier 230 which is located between the source of gamma rays 210 and the three detectors 220, 222, 224, to prevent the three detectors 220, 222, 224, from obtaining the gamma rays diffused to the inside the body of the tool 240 directly from the source of gamma rays 210. The barrier 230 is constructed from a heavy metal which considerably attenuates the gamma rays. Each of the gamma ray detectors 220, 222, 224, obtains nuclear measurements by measuring the energy distribution of the number of photons deposited at the level of the particular detector (counting rate per second).
    The nuclear tool 200 can include more or less than three gamma ray detectors. The greater the number of gamma-ray detectors located near the gamma-ray source 210, the more detail is obtained about the area near the nuclear tool 200. When more gamma-ray detectors are located at a distance from the source of gamma rays 210, an increase in details at a distance from the nuclear tool 200 can be obtained.
    The energy range applied by the nuclear tool 200 is generally less than a few hundred keV. For example, a source of Cs-137 has an energy level of 662 keV. The elements encountered by gamma rays in the downhole environment such as the wellbore 201 have very similar attenuation coefficients, which in the long term remain relatively constant over the entire energy range of interest. Therefore the total number of counting rates measured is mainly determined by the density of the materials with which the gamma rays interact along their path from the gamma ray source 210 to one of the gamma ray detectors 220, 222, 224. This is the principle of nuclear measurement underlying the gamma-gamma technique for the nuclear tool 200.
    As illustrated in FIG. 2B, the gamma rays encounter layers of material outside the nuclear tool 200 along their path. The material layers include the multi-pipe configuration and the well material within the annular spaces defined by the multi-pipe configuration. Multi-pipe configuration includes production cladding 202 and production casing 203 and well material layers include cement 204 inside the primary cement sheath (behind production cladding 202 and inside of the inner diameter 209 of the wellbore 201), the fluid of the wellbore 205 and the fluid of the casing
    207. In some applications, well material, such as wellbore fluid 205 and tubing fluid 207, are assumed to be known for procedures related to a particular wellbore application.
    Figure 3 illustrates a diagram of an example EM tool in the time domain 300 used for pipe inspection and Figure 4 illustrates a diagram of an example EM tool in the frequency domain 400 used for pipe inspection. The EM 152 tool in Figure 1 can be either the EM 300 tool or the EM 400 tool. The EM 300 tool and the EM 400 tool both include transmitter and receiver coils that transmit and receive electromagnetic energy, and both can be conventional tools. In the time domain EM tool 300, pulses are used as excitation and the transmitters and receivers are collocated. The EM 300 tool includes three co-located transmitters and receivers 310, 320, 330. As a variant, a single transmitting and receiving coil can be used, the same coil serving both as transmitter and receiver.
    The EM tool in the 400 frequency domain includes a transmitter 410 and six receivers designated by the receivers 420, 430, 440, 450, 460 and 470. The excitement of the EM 400 tool has a limited spectral distribution centered around of one or a small number of frequencies and a measurement in the field of the phasor in the stable state is carried out. Typical frequencies for the EM tool in the 400 frequency range can be in the range of 0.1 Hz to 100 Hz. Low frequencies allow deeper penetration and are important for sensitivity to the second pipe, third pipe or to deeper pipes. The higher frequencies allow the measurement of a first pipe with a lower influence on the part of the other pipes. Likewise, for the time domain EM tool 300, the late time values are indicative of characteristics or properties of deeper pipes, while the early time values are indicative of characteristics or properties of shallower pipes. Using well log signals at multiple frequencies (for the EM tool in the 400 frequency domain) or multiple points in time (for the EM tool in the 300 time domain), it is possible to resolve the properties of both the first pipe and subsequent pipes. This can be accomplished by using an inversion method where the modeled signals are mapped to the EM well log signals and the model parameters which correspond to the best match are accepted as outputs. EM well log signals are EM signals supplied or measured by an EM tool such as the EM 300 tool or the EM 400 tool.
    FIG. 5 illustrates a process diagram of an example of a workflow 500 of an inversion algorithm for determining properties of the piping, such as the thickness of the metallic piping. A series of operation instructions or code can direct the operation of a processor to execute the inversion algorithm represented by workflow 500 to determine the properties of the pipes. The processor can be part of the electronic equipment 134. In some examples a well bottom calculation device can carry out the method 500 and communicate the results to a surface calculation device via standard communication methods used in a well drilling. Method 500 generates output indicating property or properties of piping in a multi-pipe configuration by comparing the measured EM well log signals to signals from a model response, and refining the model to that an expected modeling signal is obtained which corresponds to the measured EM signals from the well logging, i.e., the EM well logging signals.
    Workflow 500 begins at step 510 by calculating an offset between the EM well log signals and the model signals. The EM well log signals can be EM signals measured by an EM tool, such as the EM 300 tool or the EM 400 tool. The model signals are also EM signals generated according to a model response based on the model settings.
    At decision step 520 it is determined whether the difference or the offset between the EM well log signals and the model signals have converged. Convergence is typically determined by the number of iterations for an iterative algorithm, or the amount of offset between the model signals and the well log signals. If convergence has occurred, a property or characteristic of the piping is provided in step 530. The workflow ends in a step 540. Multiple properties of the piping can be provided. The output of the properties of the piping supplied in step 530 may be, for example, the determined thicknesses of the individual sheaths of a multiple pipe configuration. In various examples, the piping properties determined by workflow 500 and the model that is used in workflow 500 correspond to the multiple pipe configuration.
    If convergence has not occurred, method 500 proceeds from step 520 to step 550 where the model parameters are updated. The model parameters can be: casing thickness, production cladding thickness, distance between casing and cladding, distance between production cladding and intermediate cladding, and relative eccentricity between casing and cladding. Parameters that are known before workflow 500 is completed can either be constrained during the inversion process, or can be used as inputs to workflow 500 rather than as outputs. For example, if the diameter of a pipe is known based on a given plan, then the diameter can be set to this value in the inversion workflow 500. Alternatively the known diameter of the pipe can be allowed to change within a certain percentage of the known value of the pipe diameter (i.e., constrained). The model response is then generated with the model parameters updated in step 560. The model response can be generated using a conventional method. In a step 565, calibration coefficients are received to generate the response of the model. Calibration coefficients can be provided for the first generation of the model response based on historical data. For example, the calibration coefficients can be obtained from the characterization of the tool response in a laboratory test or a computer simulation for the same type of tool.
    As mentioned above, the well integrity monitoring tool disclosed herein, such as tool 150, can be used to determine volumetric information on the well material injected into a wellbore. The properties of the piping determined via EM measurements can be used with nuclear measurements obtained by the detectors of a nuclear tool to determine the volumetric information. Piping properties, such as the measured cladding thickness, are used to determine which map or graph of relationships between well materials to use to represent the multiple pipe configuration in a wellbore. The graphs illustrated in Figure 6 and Figure 7 provide examples of the relationship between EM and nuclear measurements and volumetric information on a well material in a wellbore. The graph in Figure 6 can be drawn from experimental or modeled data. Different graphics are used depending on the well material studied. In addition, the thickness of the metal piping determined from the measurements of the EM tool as shown in Figure 5 is used to determine the particular graph to be used. Figure 6 and Figure 7 both show the relationship between the well materials for a cladding thickness and a particular well material. As in Figure 6, the determined thickness of the metal piping and the well material determines the particular relationship between the well materials to be used which corresponds to Figure 7. As for Figure 6, experimental and modeled data can also be used to generate the relationship map between the various well materials as shown in Figure 7. Different relationship maps are established for different sheath thicknesses and different well materials. Computer simulations can be used to develop relationship maps between well materials. Signal processing using a combination of data acquired from each detector of a nuclear tool, such as detectors 220, 222, 224, of nuclear tool 200, produces the measurement probe to assess the integrity of the material wells using relationship maps between particular well materials. The following discussion applies to the use of EM measurements with nuclear measurements to determine volumetric information on cement in a wellbore but a similar method can be used for other well materials in the wellbore.
    To reduce the dependence on the environment of the wellbore and increase its sensitivity to a cement sheath, an example of operation of a nuclear tool as disclosed here and of signal processing of nuclear measurements includes the definition of a signal S by taking the ratio of the counting rates of the relatively close detector (Np TOC fe) and the relatively far detector (N / Ointoi „) of the nuclear tool as represented by Equation 1 presented below.
    N g _ near
    N far Equation 1
    In the example of a nuclear tool 200, there are two relatively distant detectors, which provide a different study depth in the radial distance from the wellbore 201. The longitudinal distance between the detector and the source and the energy level of the photons emitted by the source make it possible to determine the radial depth of study (PRE). The analysis results from these two detectors serve as a quality control process to verify confidence in the evaluation of the well material. The processing method for nuclear measurements is the same for both detectors. Therefore only the method of processing a near and far detector set is discussed below, but the method also applies to the other near and far detector set in the tool configuration. For example in FIG. 2A, the relatively close detector is the first detector 220 and the relatively distant detectors are the second detector 222 and the third detector 224.
    The process of transporting photons inside materials can be the subject of a computer simulation using Monte Carlo N-Particle calculation codes (MCNP) developed by Los Alamos National Lab. The process can be understood by examining the attenuation law represented by Equation 2 below where N is the number of photons, μ is the linear attenuation coefficient, x is the distance traveled, and p is the density of the material.
    N = N o exp (- ^ g i x i p i ) 'Equation 2
    For a given well configuration with a known casing thickness and production cladding thickness, the response of the nuclear detector due to the change of material inside the primary cement sheath can be simulated using MCNP codes. Figure 6 shows an example of signal change (AS) when the annular space of the cement is completely filled with water, gas and baryte mud compared to an intact cement (a reference value). As it shows, the change in signal is proportional to the density contrast in the annular space of the cement. For a section of a wellbore having the same casing thickness and the same coating thickness of the simulation production, the signal change of the nuclear tool is an indicator of the average density behind the cladding. The curve in FIG. 6 represents a continuous function between a variation in the counting rate of the nuclear detector and the density contrast of the material. Four different measurement points that were used to adjust the curve are also shown in Figure 6.
    This is further illustrated by an example of cement distributed in the annular space, as shown in Figure 7. Figure 7 illustrates a dependence of the signal contrast of the nuclear tool to the volumetric fraction of the cement inside of a primary cement sheath. The annular space of the cement is divided into four quadrants as indicated by the three examples of the annular space of the cement 710, 720 and 730, in Figure 7. These quadrants are replaced by water to create filled to 75 % of cement 710, filled to 50% of cement 720, filled to 25% of cement 710 and filled to 0% of cement. For 75% filled with 710 cement, the water quadrant has four separate locations; for 50% filled with 720 cement, the water quadrants have two separate locations; for 25% filled with 730 cement, this is a mirror image of 75% filled with cement except that the water and cement are reversed. Figure 7 includes a line that represents the continuous function between the change in counting rate of the nuclear detector and the density contrast of the material. Multiple measurement points are shown which have been used to adjust the line.
    The signal change in each cement configuration compared to the fully cement condition is illustrated in Figure 7. As shown in Figure 7, the signal change is proportional to the volumetric percentage of the cement within the annular space of the cement, which corresponds to a change in average density. So if the signal change is calculated, the percentage of cement inside
    V c the annular space of the cement can be obtained by the relation established between AS and V c i men t as represented by Equation 3 below.
    ^ identify ~ f (4S) Equation 3
    The precision of the cement volume estimate can be deduced from Figure 7 by the propagation of errors. Different maps of relationships between well materials can be created by computer simulation for different well materials, such as a support agent, and used to determine volumetric information. The particular type of well material can be known from a given well plan or from the knowledge of the well operator.
    Figure 8 illustrates an example workflow 800 of a multi-physical algorithm for providing volumetric information on cement in a multi-pipe configuration. A similar process can also be used for other well materials. Entries for workflow 800 include a determined thickness of metal piping based on measurements obtained by an EM tool (i.e., properties of piping based on EM measurements) and on gamma ray measurements obtained by a nuclear tool (i.e., nuclear measurements). Workflow 500 provides an example of determining the thickness of metal piping that can be used as an input for workflow 800. The EM tool and the nuclear tool can be, for example, the EM tool 152 and the nuclear tool 156. The EM tool and the nuclear tool can be integrated into a single well monitoring tool, such as the well integrity monitoring tool 150.
    In a step 810, the workflow 800 determines a reference signal S based on the nuclear measurements coming from the gamma ray detectors of the nuclear tool. The reference value can be calculated by taking the average of the nuclear measurements over a depth range that is at least 2 feet, or by using a peak in the histogram in the same depth range. The nuclear tool can be an NCET.
    A delta of the signal S (Δ5) is determined in a step 820 on the basis of the nuclear measurements of the gamma ray detectors. The delta of signal S can be determined by subtracting the difference between the reference signal S of step 810 and the signal S, from the nuclear measurements of the nuclear tool. The signal delta S provides a processed nuclear measurement.
    In a step 830, a delta of the signal S for mapping the integrity of the well material is determined using the determined thickness of the metal piping. Nuclear measurement for cement integrity mapping can be performed using real measurements or computer simulations.
    The relationship map between the well materials to be used is determined in a step 840. In one example, the relationship map between the well materials is determined by using both the signal delta of the nuclear tool measurements for the mapping of the quality of the well material, as shown in Figure 6 or Figure 7, and the delta of the signal S. The workflow 800 continues until step 850 where the integrity of the well material is determined on the basis of the relationship map, as illustrated in Figure 6 or Figure 7. The functions represented by Figure 6 and Figure 7 provide examples of the nuclear part of the multi-physics algorithm which is used in step 850. Figure 6 shows 100% replacement of the material in the annulus, water, cement, or other lighter or denser material. Figure 7 shows water or cement in the annular space and the replacement of a volumetric fraction of the cement with water at a time. Figure 9 is an example of the results from step 850. Workflow 800 ends in step 860.
    Figure 9 illustrates a simulated diagram over an extended length of a wellbore with multiple cement conditions. The nuclear tool can be lowered into production casing and generate an extended diagram representing the volume of cement behind the cladding. The results of the simulation are provided in Figure 9 according to computer modeling. A well can be simulated using five separate sections of cement integrity. Each section represents 20 feet including cement integrity scenarios such as 100% filled with cement, 75% filled with cement, 50% filled with cement, 25% filled with cement and 0% filled with cement. The cementless area is filled with water instead of it.
    The simulated diagram also considers the effect of detachment. As a result, diagrams for two types of well integrity were generated. One type begins peeling on the cladding side and the area containing water spreads to the formation side; the other type begins peeling from the formation side and the area containing water spreads to the cladding side.
    The results of the diagram simulate a logging speed of 10 feet / min. Each data point represents a sum of measurements within 3 inches of depth. An observation in Figure 9 is that 25% difference in the filling of the cement is differentiable from noise and uncertainty, which is compatible with the analysis in Figure 7. A second observation is that the position of the absence of cement inside the annular space is indistinguishable from this same amount of lack of cement.
    Figure 10 illustrates a block diagram of an exemplary well integrity monitoring system 1000 constructed according to the principles disclosed herein. The well integrity monitoring system 1000 includes a nuclear tool 1010 which obtains nuclear measurements from a wellbore having a cladding configuration and an EM tool 1020 which obtains EM measurements from the metal tubing of the configuration cladding. An integrity calculation device 1030 receives nuclear measurements and EM measurements and determines an integrity of the well material, such as volumetric information on a well material inside the annular spaces of the well defined by the metallic piping. The components of the well integrity monitoring system 1000 can be coupled in communication with each other by conventional connections and protocols used in the industry.
    The well integrity monitoring system 1000, or at least some of the components thereof, can be integrated within a single body or shell. For example, the nuclear tool 1010 and the EM tool 1020 can be inside a single envelope 1015 as represented by the dotted lines in FIG. 10. The integrity calculation device 1030 can be located in a casing 1025 with the nuclear tool 1010 and the EM tool 1020 or may be located on the surface of a wellbore. For example, the integrity calculator can be part of the electronic equipment 134. The integrity calculator 1030 can be programmed to perform the algorithms shown in the workflows of Figure 5 and Figure 8 The integrity calculator 1030 can also be configured to control the operations of the nuclear tool 1010 and the EM tool 1020. For example, the integrity calculator 1030 can be configured to coordinate the operations of the nuclear tool 1010 and the EM 1020 tool to obtain associated nuclear and EM measurements which correspond to a particular depth or depths of the wellbore.
    The integrity calculation device 1030 includes an interface 1032 configured to receive the EM measurements and the nuclear measurements obtained from a wellbore by a well integrity monitoring tool, as disclosed here. The nuclear and EM measurements can be signals from the nuclear tool 1010 and the EM tool 1020 which are processed before sending to the interface 1032. The EM measurements provide the properties of the piping of metallic pipes in a borehole. Nuclear measurements provide information relating to the density of the well material in the annular spaces defined by the metal pipes. The integrity calculator also includes a processor 1034 configured to determine the volumetric information of a well material within the annular spaces of the well defined by the metal pipes of the cladding configuration. The processor 1034 uses EM and nuclear measurements to determine the volumetric information. The integrity calculating device 1030 also includes a memory 1036. The memory 1036 can be a non-volatile memory which stores operation instructions for directing the operation of the processor 1034. The operation instructions can correspond to algorithms such as as represented by the workflows of Figure 5 and Figure 8. Memory 1036 can also store various maps of relationships between well materials which are used to determine the volumetric information on the well material. The volumetric information provided by the integrity calculation device can be provided to a user or to a well operator and used to make a decision to intervene on the well.
    FIG. 11 illustrates a process diagram of an example process 1100 of using a nuclear tool and an EM tool for monitoring the well integrity of a wellbore having a multiple pipe configuration . The 1100 method advantageously combines the measurement results of two types of tools with different physical principles and provides a more precise downhole technique for analyzing the volumetric information on the well materials behind the metal pipe multilayers in the configuration with multiple pipes. Some of the steps of the method 1100 can be carried out, for example, by a processor of the electronic equipment 134 or the control device 160. In addition, some of the steps of the method 1100 can be carried out by the integrity calculation device 1030 The method 1100 starts in a step 1105.
    In a step 1110, a nuclear tool is operated in a wellbore to perform a nuclear measurement at a depth of the wellbore. The nuclear tool can be operated at multiple depths in the wellbore. The nuclear tool can be the nuclear tool 200 as disclosed here.
    Method 1100 continues with the operation of an EM tool in the wellbore to perform an EM measurement at the depth of the wellbore. The EM tool can be operated at multiple depths in the wellbore that correspond to the operation of the nuclear tool. The EM tool can be the EM 300 or 400 tool as disclosed here. In some examples, step 1120 can take place before or during step 1110.
    In step 1130, a plurality of properties of the piping of the multi-pipe configuration is determined at depth using EM measurements. Piping properties can be determined, for example, by the workflow described in Figure 5.
    Using the properties of the piping, a processed nuclear measurement is determined from the nuclear measurement in step 1140. Processing the nuclear measurement to determine the processed nuclear measurement may include calculating a reference value for the measurements of the nuclear tool over a range of depths of the wellbore and subtracting the reference value of the nuclear measurement to produce the processed nuclear measurement.
    In my step 1150, the processed nuclear measurement is used to determine an integrity of a well material at the depth and within an annular space defined by the multiple pipe configuration. The processed nuclear measurement can be used with a well material relationship map to determine the integrity of the well material.
    In a step 1160, a decision to intervene on the well can be made using the integrity of the well material. For example, a well operator may employ the integrity of the well material for dismantling the well. The method 1100 then ends in a step 1170.
    The present disclosure provides a method for evaluating the integrity of cement or other well material in multiple annular spaces for a well having a multiple pipe configuration. The disclosure combines the measurement results of two types of tools of different physical principles and provides a mechanism for generating a more accurate downhole technique for analyzing the volumetric information on the cement or other well material behind the cladding multilayers. . The disclosed method, system and tool use the results of EM and nuclear measurements, such as gamma radiation, to provide a better estimate of the volumetric information on the cement or other well material behind the cladding. The features of the disclosure may find application in a multiple train assessment and offer an advantageous position in the emerging well dismantling market. The multi-physical approach improves the quality of measurement and increases confidence in the output of data.
    In one aspect, the disclosure provides a well integrity monitoring tool. In another aspect, the disclosure provides a device for calculating integrity. In yet another aspect, a system is also disclosed which includes the well integrity calculating tool and device. The integrity calculation device receives the nuclear and EM measurements and determines volumetric information on a well material inside the annular spaces of the well defined by the metallic piping.
    Specialists in the field who are concerned by this request will understand that other additions, deletions, substitutions and additional modifications can be made to the embodiments described.
    The apparatuses, systems, or methods described above or at least a portion thereof can be implemented or realized by various processors, such as processors or digital data computers, in which the processors are programmed or store programs or executable sequences of software instructions for performing one or more of the process steps or the functions of the devices or systems. The software instructions of such programs can represent algorithms and be encoded in machine-executable form on non-transient digital data storage media, e.g. magnetic or optical disks, random access memory (RAM), magnetic hard drives, flash memories and / or read only memory (ROM), to allow various types of digital data processors or computers to perform one, more or all of the steps in one or more of processes or functions described above of the system described here.
    Certain embodiments disclosed here may also relate to computer storage products with a non-transient computer readable medium which present a program code thereon for carrying out various operations implemented by computer which include at least a part of the devices, systems or perform or direct at least some of the process steps mentioned here. A non-transient medium used here designates all of the computer-readable media with the exception of transients, which propagate signals. Examples of non-transient computer readable media include, but are not limited to: magnetic media such as hard disks, floppy disks and magnetic tape cassettes; optical media such as CD-ROM discs; magneto-optical media such as flexible optical discs; and computer devices that are specifically configured to store and execute program code, such as ROM and RAM devices. Examples of program code include both machine code, such as that produced by a compiler, and files containing high-level code that can be executed by the computer using an interpreter.
    In interpreting the disclosure, all terms should be interpreted as broadly as possible in accordance with the context. In particular, the terms "comprises" and "comprising" should be interpreted as designating elements, components, or steps in a non-exclusive manner, indicating that the elements, components, or designated steps may be present, or used, or combined with other elements, components, or steps which are not explicitly mentioned. Unless defined otherwise, all of the technical and scientific terms used here have the same meaning as that commonly understood by those skilled in the art concerned by this disclosure. Although any method and material similar or equivalent to those described herein can also be used in the practice or testing of the present disclosure, a limited number of examples of methods and materials are described here.
    Various aspects of the disclosure can be claimed including the apparatuses, systems and methods disclosed herein. The aspects disclosed here include:
    A. A method, using a nuclear tool and an EM tool, for monitoring the well integrity of a wellbore having a multiple pipe configuration, the method including: operating a nuclear tool in the wellbore for performing a nuclear measurement at a depth of the wellbore, operating an EM tool in the wellbore to perform an EM measurement at the depth of the wellbore, determining a plurality of properties piping of the multiple pipe configuration to depth using EM measurement, determining, using piping properties, a processed nuclear measurement from nuclear measurement, and using the processed nuclear measurement to determine an integrity of a well material at the depth and within an annular space defined by the multiple pipe configuration.
    B. A well integrity monitoring tool for a wellbore, including: an EM tool configured to obtain EM measurements, at different depths of a wellbore, associated with metal pipes in a multiple pipe configuration the wellbore, in which the EM measurements correspond to the properties of metal pipe work, and a nuclear tool configured to obtain nuclear measurements at the various depths of the wellbore, in which the nuclear measurements correspond to the volumetric information on a material well which is behind a multilayer of metal pipes.
    C. A well integrity monitoring system, including: a well integrity monitoring tool for a wellbore having an EM tool configured to obtain EM measurements at depths of a wellbore having a configuration multi-pipe, in which the EM measurements correspond to the properties of metal pipe piping of the multi-pipe configuration, and a nuclear tool configured to obtain nuclear measurements at the depths of the wellbore, and including a device for calculating integrity having an interface configured to receive EM measurements and nuclear measurements, and a processor configured to use both EM measurements and nuclear measurements to determine an integrity of a well material at one of the depths and at inside an annular space defined by the multiple pipe configuration.
    Each of aspects A, B and C may have one or more of the following additional elements in combination;
    Element 1: wherein the multiple pipe configuration includes tubing and at least one cladding train. Element 2: in which the determination of the nuclear measurement processed includes the calculation of a reference value for nuclear measurements of the nuclear tool at multiple depths of the wellbore. Element 3: wherein the determination of the nuclear measurement processed further includes subtracting the reference value of the nuclear measurement to produce the nuclear measurement processed. Element 4: wherein the nuclear tool includes an omnidirectional gamma ray source, at least one gamma ray detector, and a barrier which is located between the omnidirectional gamma ray source and the at least one gamma ray detector. Element 5: in which the nuclear tool has at least three gamma ray detectors. Element 6: in which the EM tool is a tool in the frequency domain or a tool in the time domain. Element 7: in which the plurality of properties of the piping includes several of the properties selected from the list consisting of: casing thickness, production cladding thickness, distance between the casing and the cladding, distance between the production cladding and the cladding intermediate, and relative eccentricity between the casing and the cladding. Element 8: in which at least one of the properties of the piping is calculated using an inversion process. Element 9; in which the well material is selected from the list consisting of: cement, water, muddy sediments, radioactive marker material, non-radioactive marker material and proppants. Element 10: in which the nuclear and EM tools are in the same tool train. Element 11: in which the nuclear tool and the EM tool are collocated in a single body. Element 12: in which the nuclear tool and the EM tool are collocated in a single body. Element 13: in which the nuclear tool and the EM tool are in the same tool train. Element 14: wherein the nuclear tool includes an omnidirectional gamma ray source, at least one gamma ray detector, and a barrier which is located between the omnidirectional gamma ray source and the at least one gamma ray detector, and the EM tool is a tool in the frequency domain or a tool in the time domain. Element 15: in which the nuclear tool has at least three gamma ray detectors. Element 16: wherein the EM measurements correspond to information relating to the thickness and spacing of at least some of the metal pipes in the multi-pipe configuration. Item 17: wherein the multiple pipe configuration includes tubing and at least one cladding train. Item 18: wherein the integrity of the well material is determined by the volumetric information on the well material which is behind a multilayer of the metallic pipes of the multiple pipe configuration. Element 19: wherein the processor is configured to determine the integrity of the well material by calculating the plurality of piping properties from EM measurements, processing nuclear measurements to produce a processed nuclear measurement using the properties of piping, and establishment of a relationship between the nuclear measurement processed and the integrity of the well material by using a relationship map between the well materials. Element 20: wherein processing includes calculating a reference value from nuclear measurements at multiple depths of the wellbore and subtracting the reference value from one of the nuclear measurements to produce the processed nuclear measurement . Element 21: wherein the processor is configured to determine at least one of the properties of the piping using an inversion process.
    权利要求:
    Claims (4)
    [1" id="c-fr-0001]
    THE CLAIMS ARE AS FOLLOWS:
    1. Well integrity monitoring tool (150) for a wellbore, comprising:
    an electromagnetic (EM) tool (152; 300; 400; 1020) configured to obtain EM measurements, at different depths of a wellbore (101; 201), associated with metal pipes of a multiple pipe configuration (140 ) the wellbore, in which the EM measurements correspond to the properties of the piping of metal pipes; and a nuclear tool (156; 200; 1010) configured to obtain nuclear measurements at different depths of the wellbore, wherein the nuclear measurements correspond to the volumetric information on a well material which is behind a multilayer of metallic pipes.
    [2" id="c-fr-0002]
    2. Well integrity monitoring tool (150) according to claim 1 wherein the nuclear tool (156; 200; 1010) and the EM tool (152; 300; 400; 1020) are collocated in a single body. (240), or in which the nuclear tool and the EM tool are in the same tool train.
    [3" id="c-fr-0003]
    3. Well integrity monitoring tool (150) according to any one of claims 1 to 2, wherein the nuclear tool (156; 200; 1010) includes a source of omnidirectional gamma rays (210), at least a gamma ray detector (220, 222, 224), and a barrier (230) which is located between the omnidirectional gamma ray source and the at least one gamma ray detector, and the EM tool (152; 300; 1020) is a tool in the frequency domain or a tool in the time domain, and optionally, in which the nuclear tool has at least three gamma ray detectors.
    [4" id="c-fr-0004]
    4. Well integrity monitoring tool (150) according to any one of claims 1 to 3, in which the EM measurements correspond to information relating to the thickness and the spacing of at least some of the pipes. of multi-pipe configuration (140).
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    同族专利:
    公开号 | 公开日
    BR112019019385A2|2020-04-14|
    WO2018236495A1|2018-12-27|
    US20200109626A1|2020-04-09|
    GB201916118D0|2019-12-18|
    GB2575940A|2020-01-29|
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    法律状态:
    2019-05-23| PLFP| Fee payment|Year of fee payment: 2 |
    2020-05-01| PLSC| Search report ready|Effective date: 20200501 |
    2021-05-07| RX| Complete rejection|Effective date: 20210402 |
    优先权:
    申请号 | 申请日 | 专利标题
    US201762522518P| true| 2017-06-20|2017-06-20|
    US62522518|2017-06-20|
    PCT/US2018/032739|WO2018236495A1|2017-06-20|2018-05-15|Apply multi-physics principle for well integrity evaluation in a multi-string configuration|
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