System and method for multiple mechanical caliper measurements

Abstract

The systems and methods disclosed herein are generally directed to an interpretation system that can receive measurements from a multi-finger caliper tool and output various characteristics of a wellbore based on the measurements and / or models (e.g., computer models with algorithms) related to the multi-finger caliper tool. For example, the interpretation system can generate and output a defect map (e.g., a defect map according to axial and circumferential positions) based on an interpretation of the measurements. In another example, the interpretation system can determine a state of the wellbore based on the interpretation. If the state is definitive, the interpretation system can instruct one or more components of a hydrocarbon wellsite to initiate a production operation. If the state is not definitive (e.g., corrosion), the interpretation system can identify a zone of interest within the wellbore and / or perform a corrective action at the zone of interest.

Description

Technical Field

[0001] This disclosure generally relates to monitoring various characteristics at hydrocarbon well sites. More specifically, this disclosure relates to providing an interpretation system for determining various characteristics of the wellbore within a hydrocarbon well site based on multi-finger caliper measurements and one or more models obtained from the hydrocarbon well site. Background Technology

[0002] Before and / or during production operations, information relating to hydrocarbons extracted from the well and / or equipment used for transporting, storing, or processing the extracted hydrocarbons can be collected at the well (e.g., the well site) or at various locations along the pipeline network. In some cases, it may be beneficial to determine various characteristics of the wellbore before, during, and / or after production operations. To determine these characteristics, measurements indicating the inner surface and / or radius of the wellbore can be generated using one or more multi-finger caliper tools traversing the wellbore. Therefore, it may be beneficial to obtain accurate predictions of various wellbore characteristics by interpreting measurements from multi-finger caliper tools. Summary of the Invention

[0003] The following provides an overview of certain embodiments disclosed herein. It should be understood that these aspects are presented merely to provide the reader with a brief overview of these particular embodiments, and these aspects are not intended to limit the scope of this disclosure. In fact, this disclosure may cover various aspects that may not be set forth below.

[0004] In one embodiment, a system may include: a multi-finger caliper tool configured to be positioned within a wellbore in a hydrocarbon field, wherein the multi-finger caliper tool is configured to generate measurements indicating the inner surface of the wellbore; a component coupled to the multi-finger caliper tool and configured to adjust the position of the multi-finger caliper tool within the wellbore; and a computing system communicatively coupled to the multi-finger caliper tool. The computing system may include processing circuitry and a memory storing instructions. When executed by the processing circuitry, the instructions may cause the processing circuitry to perform an autonomous workflow to instruct the component to adjust the position of the multi-finger caliper tool within the wellbore to generate the measurements, convert the measurements into radius values ​​based on at least one of a plurality of models, and generate a corrected radius value based on the radius value and a second of the plurality of models. When executed by the processing circuitry, the instructions may also cause the processing circuitry to generate a defect map indicating a portion of the wellbore based on the corrected radius value and instruct a display to show the defect map.

[0005] In one embodiment, the method may include, via processing circuitry, instructing components of a hydrocarbon well site to adjust the position of a multi-finger caliper tool within the wellbore of the hydrocarbon well site to generate a set of measurements, receiving from the multi-finger caliper tool a set of measurements indicating the inner surface of a portion of the wellbore, and converting the set of measurements into a set of radius values ​​based on at least one of a plurality of models. The method may further include, via processing circuitry, generating a set of corrected radius values ​​based on the set of radius values ​​and a second model of the plurality of models, and via processing circuitry, generating a defect map indicating that portion of the wellbore based on the set of corrected radius values. The method may further include, via processing circuitry, identifying one or more defects within that portion of the wellbore based on the defect map, and via processing circuitry, instructing a display to show a graphic including the set of corrected radius values ​​and the defect map.

[0006] In one embodiment, a system may include: a multi-finger caliper tool configured to be positioned within a wellbore in a hydrocarbon field, wherein the multi-finger caliper tool is configured to generate measurements indicating the inner surface of the wellbore; a component coupled to the multi-finger caliper tool and configured to adjust the position of the multi-finger caliper tool; and a computing system communicatively coupled to the multi-finger caliper tool. The computing system may include processing circuitry and a memory storing instructions. When the processing circuitry executes the instructions, the instructions may cause the processing circuitry to perform an autonomous workflow to perform a first calibration of the multi-finger caliper tool by instructing the component to adjust the position of the multi-finger caliper tool through one or more pipes of known diameter to generate a first calibration measurement while passing through one or more pipes; instructing the component to adjust the position of the multi-finger caliper tool within the wellbore to generate a measurement while passing through the wellbore; and performing a second calibration of the multi-finger caliper tool by instructing the component to adjust the position of the multi-finger caliper tool through one or more pipes of known diameter to generate a second calibration measurement while passing through one or more pipes. When executed by the processing circuit, the instruction can cause the processing circuit to convert the measured value into a radius value based on a first calibration measurement value, a second calibration measurement value, and at least one of multiple models, generate a corrected radius value based on the second model among the multiple models, generate a defect map indicating a portion of the wellbore based on the corrected radius value, and instruct the display to show the defect map.

[0007] Various modifications to the features described above may exist in relation to various aspects of this disclosure. Other features may also be incorporated into these aspects. These modifications and additional features may exist individually or in any combination. For example, various features discussed below in relation to one or more of the illustrated embodiments may be incorporated individually or in any combination into any of the foregoing aspects of this disclosure. The brief overview presented above is intended only to familiarize the reader with certain aspects and context of embodiments of this disclosure and is not intended to limit the scope of the claimed subject matter. Attached Figure Description

[0008] These and other features, aspects, and advantages of this disclosure will become better understood when the following detailed description is read with reference to the accompanying drawings, in which the same reference numerals denote the same parts throughout the drawings, and in which:

[0009] Figure 1 A schematic diagram of an exemplary hydrocarbon field capable of producing and processing hydrocarbons according to embodiments of the present disclosure is shown;

[0010] Figure 2 The communicative connection according to an embodiment of the present disclosure is illustrated. Figure 1 A block diagram of the interpretation system for multi-finger caliper tools used in hydrocarbon fields;

[0011] Figure 3 An embodiment according to this disclosure is shown. Figure 2 The system interprets the flowchart of the operation of the multi-finger caliper tool and interprets the measurement values ​​from the multi-finger caliper tool;

[0012] Figure 4 The presentation of embodiments according to this disclosure is shown by Figure 2 The graphical user interface (GUI) of an electronic display for implementing defect analysis technology in the explanation system;

[0013] Figure 5 The embodiments of the present disclosure are shown. Figure 2 The interpretation system is a model used to determine various characteristics of the wellbore;

[0014] Figure 6 The illustration shows an embodiment of the present disclosure for aligning measurements from a multi-finger caliper tool and... Figure 2 A flowchart illustrating an example method for interpreting system-identified defects and / or defect repetitions; and

[0015] Figure 7 The presentation of embodiments according to this disclosure is shown by Figure 2 The system interprets the defect diagrams and defect repetition indices generated by the electronic display via a GUI. Detailed Implementation

[0016] The following outlines certain embodiments commensurate with the scope of this disclosure. These embodiments are not intended to limit the scope of this disclosure, but are merely intended to provide a brief overview of some of the disclosed embodiments. In fact, this disclosure may cover a variety of forms that may be similar to or different from the embodiments set forth below.

[0017] As used herein, the terms “connection” or “linked to” may indicate the establishment of a direct or indirect connection (e.g., where the connection may exclude or include intermediate or intervening parts between those connected), and are not limited to either, unless clearly so cited. The term “set” may refer to one or more items. Similar or identical reference numerals are used in the accompanying drawings to identify common or identical elements whenever possible. The drawings are not necessarily drawn to scale, and for clarity, certain features and views in the drawings may be shown enlarged to scale.

[0018] As used herein, the terms “inner” and “outer”; “upper” and “lower”; “upper part” and “lower part”; “upward” and “downward”; “above” and “below”; “inward” and “outward”; and other similar terms as used herein refer to their relative positions to each other and are not intended to indicate a particular direction or spatial orientation. The terms “connected,” “linked,” “connected to,” “connected to,” “connected with,” and “to connect” mean “directly connected to” or “connected to” via one or more intermediate elements or components.

[0019] Furthermore, when describing elements of various embodiments of this disclosure, the articles “a,” “an,” and “the” are intended to indicate the presence of one or more elements. The terms “comprising,” “including,” and “having” are intended to be inclusive and mean that additional elements may exist in addition to those listed. Additionally, it should be understood that references to “an embodiment,” “an embodiment,” or “some embodiments” in this disclosure are not intended to be construed as excluding the existence of additional embodiments that also include the described features. Furthermore, the phrase A “based on” B is intended to indicate that A is at least partially based on B. Moreover, unless clearly stated otherwise, the term “or” is intended to be inclusive (e.g., logical OR) rather than exclusive (e.g., logical XOR). In other words, the phrase A “or” B is intended to mean A, B, or both A and B.

[0020] A hydrocarbon well site (e.g., a hydrocarbon well, a well) may include multiple components that facilitate the extraction, processing, and distribution of hydrocarbons (e.g., oil) from the well or well site. For example, a hydrocarbon well site may include one or more wellbores (e.g., boreholes) extending into the corresponding subsurface reservoir. A hydrocarbon well site may also include one or more multi-finger caliper tools that pass through the wellbore and generate measurements indicating the inner surface of the wellbore, the radius of the wellbore, and / or corrosion indices corresponding to the wellbore. The wellbore may include various tubing, conduits, casing, liners, and tubing strings used at the hydrocarbon well site, such as directly in the wellbore and / or connected to the wellbore via the wellhead, tree trunk, distribution manifold, or any combination thereof. As used herein, a wellbore may refer to any of the tubing, conduits, casing, liners, and tubing strings that can be connected to and / or directly positioned within the wellbore. However, measurements from multi-finger caliper tools may include differences in depth, radius, and / or azimuth. Therefore, several processing steps can be performed to interpret (e.g., process) measurements from multi-finger caliper tools and generate various characteristics of the wellbore. For example, processing steps can identify defects caused by axial tool scraping or chiseling of the wellbore's inner surface, single-point defects caused by corrosion, or any combination thereof. A wellbore may include dozens to hundreds of defects, and verifying each defect across different multi-finger caliper measurements can be time-intensive and resource-intensive. In practice, obtaining various characteristics of the wellbore based on measurements from multi-finger caliper tools can be difficult, resource-intensive, and / or time-consuming.

[0021] With this in mind, embodiments of this disclosure generally relate to an interpretation system (e.g., a processor-based monitoring and analysis system and / or computing device) that can receive measurements from a multi-finger caliper tool and output various characteristics of the wellbore based on the measurements and / or a model associated with the multi-finger caliper tool (e.g., a computer model with an algorithm). Although the embodiments described below are presented in the context of a wellbore, these embodiments can be used for any tubing, pipe, or conduit that can be inspected by a multi-finger caliper tool. Furthermore, any models discussed below are intended to include various computer models, machine learning, and / or artificial intelligence (AI). Computer models can include three-dimensional models of the well site, geological formations, and wellbore. Computer models can include computational fluid dynamics (CFD) models, reservoir simulation models, geological models, digital twin models for equipment and tools (e.g., multi-finger caliper tools), or any combination thereof. For example, the interpretation system can use one or more models to interpret measurements from a multi-finger caliper tool without user intervention. In another example, the interpretation system can generate and output corrosion analysis and / or defect maps of the wellbore (e.g., defect maps based on axial and circumferential locations) based on the interpretation. In yet another example, the interpretation system can determine the status of the wellbore and / or hydrocarbon well site based on the interpretation. If the status is clear, the interpretation system can instruct one or more components of the hydrocarbon well site to initiate production operations and / or send notifications to user equipment indicating the status. If the status is unclear (e.g., error), the interpretation system can identify intervals of interest (i.e., location within the wellbore, positioning within the wellbore) based on the interpretation. The interpretation system can send notifications to user equipment and / or electronic displays indicating the status, intervals of interest, tools of interest, or any combination thereof. The interpretation system can instruct one or more components to initiate wellbore repairs at the interval of interest, send notifications instructing changes to tools located within the wellbore, control one or more aspects of the hydrocarbon accumulation site (e.g., adjusting valve positions, adjusting pump or compressor speeds, and / or adjusting chemical injections into the well) and / or instruct tools to return to the surface, etc. Therefore, the interpretation system can improve production operations within the hydrocarbon well site.

[0022] Keeping this in mind, in some embodiments, the interpretation system can perform calibration of a multi-finger caliper tool in three steps: master tool calibration, pre-operation calibration, and post-operation calibration. During master calibration, the raw electrical measurements of the multi-finger caliper tool can be converted into radius values ​​based on a relationship established by passing the tool through a pipe of known diameter and at different temperatures. Calibration can be performed as part of a quality control step for the multi-finger caliper tool to identify deviations, check the tool's properties against other quality indices, thereby improving and / or validating the accuracy and / or reliability of measurements produced by the multi-finger caliper tool. During pre-operation and / or post-operation calibration, the raw electrical measurements of the multi-finger caliper tool can be converted into radius values ​​based on a relationship established by passing the tool through a pipe of known diameter at ambient temperature. Therefore, the interpretation system can correct for errors in measurements introduced by tool eccentricity, finger wear, finger offset, etc. The interpretation system can store the measurements from master tool calibration, pre-operation calibration, and post-operation calibration, along with the corresponding relationships, as one or more models in memory and / or storage devices.

[0023] After receiving measurements from a multi-finger caliper tool, the interpretation system can apply one or more models to the measurements to further adjust (e.g., automatically correct) them without user intervention. For example, the interpretation system can apply at least one model (e.g., a first model) to the measurements, which indicates a relationship established by passing the multi-finger caliper tool through a pipe of known diameter, to convert electrical measurements into radius values ​​and / or reduce or eliminate the original measurement errors introduced by the multi-finger caliper tool. In another example, the interpretation system can adjust the radius values ​​based on a second model indicating an elliptical shape to remove outliers. The elliptical shape may represent the borehole diameter.

[0024] Using adjusted measurements, the interpretation system can generate and output various wellbore properties based on an additional model without user intervention. For example, the interpretation system can identify defects (e.g., protrusions, grooves, corrosion, cracks, holes, etc.) along the inner surface of the wellbore based on adjusted radius values ​​(e.g., corrected radius values) and the frequency of repetition of each defect across different multi-finger caliper measurements to verify (e.g., validate) the defects. The interpretation can identify multiple defects within a portion of the wellbore. The interpretation system can group the defects based on the relative distance between each defect. The interpretation system can also determine the wellbore strength of that portion of the wellbore based on the grouped defects and / or a third model indicating mechanical and / or stress considerations. The interpretation system can also generate and output a corrosion analysis of the wellbore based on adjusted radius values ​​and threshold radius values. The interpretation system can output a summary table of corrosion status and / or characteristics for each collar and joint in the wellbore. Corrosion status can include the percentage of corrosion, corrosion thickness, corrosion length, etc. These characteristics can include minimum inner diameter, maximum drilling progress, etc. In this way, the interpretation system can generate and output various attributes of the wellbore based on measurements and / or models.

[0025] In some cases, the interpretation system can also generate composite measurements with enhanced resolution (e.g., high resolution) by identifying and merging measurements from the same portion of the wellbore acquired under different conditions from different multi-finger caliper tools. For example, the interpretation system can align measurements in depth and / or azimuth. The system can then generate composite measurements by merging the aligned measurements. The interpretation system can interpret the composite measurements to identify various wellbore properties based on a model. In this way, the interpretation system can output various wellbore properties without user intervention.

[0026] Through introduction, Figure 1 A schematic diagram of an exemplary hydrocarbon field 10 is shown, in which hydrocarbon products such as crude oil and natural gas can be extracted, processed, and stored from the ground. According to this embodiment, a dataset related to the operation of the hydrocarbon field 10 can be employed. Figure 1 As shown, hydrocarbon field 10 may include multiple components or facilities corresponding to wells, processing facilities, collection components, distribution networks, etc. Various factors are considered during the design phase, when planning the types of components to be used at hydrocarbon field 10, the locations of the components at hydrocarbon field 10, and other design characteristics.

[0027] The hydrocarbon field 10 may include multiple wells 12 disposed within the geological formation. As used herein, well 12 may generally refer to physical components such as drilling platform 16 and wellbore 18 and / or general areas of the reservoir to be extracted (e.g., reservoir intervals). Drilling operations may include drilling wellbore 18, injecting drilling fluid into wellbore 18, performing casing operations within wellbore 18, etc. For example, this embodiment relates to an interpretation system that identifies certain perforated areas of wellbore 18 based on a first set of measurements and / or a second set of measurements to improve drilling and / or production operations. In addition to including drilling platform 16, hydrocarbon field 10 may also include surface equipment 20, which may perform operations such as cementing operations, logging operations for detecting the condition of wellbore 18, etc. Therefore, surface equipment 20 may include equipment for storing cement slurry, drilling fluid, displacement fluid, isolation fluid, chemical washing fluid, etc. Surface equipment 20 may include piping and other materials for delivering the various fluids described above into wellbore 18. Ground equipment 20 may also include pumps and other equipment (e.g., batch mixers, centrifugal pumps, fluid additive metering systems, tanks, etc.) that can fill the interior of the casing column with the aforementioned fluid.

[0028] In addition to equipment used for drilling operations, a hydrocarbon field may also include multiple well devices that can control the flow of hydrocarbons extracted from well 12. For example, well devices in hydrocarbon field 10 may include pumping unit 22, submersible pump 24, well tree 26, etc. When the bottom hole pressure of well 12 is insufficient to extract hydrocarbons to the surface, pumping unit 22 can mechanically lift hydrocarbons (e.g., oil) out of well 12. Submersible pump 24 may be an assembly that can be submerged in a pumpable hydrocarbon fluid. Therefore, submersible pump 24 may include a hermetically sealed motor so that fluid cannot penetrate the seals and enter the motor. Furthermore, the hermetically sealed motor can push hydrocarbons from the subsurface area or reservoir to the surface. Well tree 26 may be an assembly of valves, spools, and fittings for a natural flow well. Therefore, well tree 26 can be used for oil wells, gas wells, water injection wells, water treatment wells, gas injection wells, condensate wells, etc. For reference, well 12 may be part of a first stratification level, and the well device for extracting hydrocarbons from well 12 may be part of a second stratification level above the first stratification level. Each layer level may include multiple components, and the currently disclosed technology can take these levels into account when determining the design scheme of hydrocarbon field 10.

[0029] After hydrocarbons are extracted from the surface via the well equipment, the extracted hydrocarbons can be distributed to other equipment through the network of pipelines 28. That is, the well equipment of the hydrocarbon field 10 can be connected together via the network of pipelines 28. In addition to the well equipment mentioned above, the network of pipelines 28 can be connected to other collection or aggregation components, such as wellhead distribution manifolds 30, separators 32, storage tanks 34, etc.

[0030] In some embodiments, the pumping unit 22, submersible pump 24, well tree 26, wellhead distribution manifold 30, separator 32, and storage tank 34 may be connected together via a network of pipelines 28. The wellhead distribution manifold 30 can collect hydrocarbons that may have been extracted by the pumping unit 22, submersible pump 24, and well tree 26, allowing the collected hydrocarbons to be directed to various hydrocarbon processing or storage areas within the hydrocarbon field 10. The separator 32 may include a pressure vessel that can separate well fluids produced from oil and gas wells into separate gaseous and fluid components. For example, the separator 32 can separate hydrocarbons extracted by the pumping unit 22, submersible pump 24, or well tree 26 into oil, gas, and water components. After the hydrocarbons have been separated, each separated component can be stored in a specific storage tank 34. The hydrocarbons stored in the storage tank 34 can be transported via pipelines 28 to transport vehicles, refineries, etc.

[0031] In some cases, hydrocarbons may corrode the inner surface of the wellbore 18, which may weaken portions of the wellbore 18 over time. For example, corrosion may weaken the tubing, casing, and / or liner of the wellbore 18. In other cases, tools may be placed into the wellbore 18 before, during, and / or after production operations. When tools traverse within the wellbore 18, they may scrape (e.g., mark, scratch) a portion of the inner surface of the wellbore 18, which may reduce the strength of the wellbore 18.

[0032] Although the hydrocarbon field 10 has been described above with reference to certain components, it should be understood that the hydrocarbon field 10 may include additional, fewer, or different components. For example, while the above discussion pertains to an onshore hydrocarbon field 10, this embodiment may also include an analysis of an offshore hydrocarbon field 10 and its components. That is, the embodiments described herein are intended to identify segments of interest for any suitable hydrocarbon field that may include various types of components related to hydrocarbon production and distribution. In this way, it is provided... Figure 1 The components depicted herein serve as example scenarios in which the embodiments described herein can be implemented. Therefore, the embodiments disclosed herein should not be limited to... Figure 1 The components listed in the document.

[0033] With this in mind, the embodiments described herein may include systems and methods for determining various characteristics of wellbore 18 (such as the tubing, casing, and / or liner of wellbore 18) prior to and / or during production operations. For example, as Figure 2 As shown, the interpretation system 50 can be derived from, for example... Figure 2 The multi-finger caliper tool 52 shown receives at least two sets of measurements, interprets the measurements, and refers to the following... Figure 2-7 The process described in more detail determines various characteristics of wellbore 18.

[0034] Now refer to Figure 2The multi-finger caliper tool 52 may include a body portion 54, a first tool portion 52A having a first finger array 56A coupled to the first body portion 54A, and a second tool portion 52B having a second finger array 56B coupled to the second body portion 54B (collectively referred to herein as "finger array 56" and "body portion 54"). As shown, the body portion 54 may be coupled to and / or support the finger array 56. The multi-finger caliper tool 52 may include any suitable number of portions 52 and / or finger arrays 56. Each array of fingers 56 may include any suitable number of fingers that can transition between a collapsed configuration and an extended configuration. For example, each of the first finger array 56A and the second finger array 56B may include 10, 20, 30, 40, 50, 60, 70, 80, 90, or 100 fingers arranged circumferentially around the central axis of the respective first tool portion 52A and second tool portion 52B. The collapsed configuration has a first finger array 56A and a second finger array 56B that are substantially flush with and / or recessed into the surfaces of the first tool portion 52A and the second tool portion 52B, such that the first finger array 56A and the second finger array 56B are substantially parallel to the central axis. In contrast, the extended configuration has a first finger array 56A and a second finger array 56B that are angled outward from the surfaces of the first tool portion 52A and the second tool portion 52B, such that the first finger array 56A and the second finger array 56B are oriented at an acute angle of about 10 to 80 degrees, 20 to 70 degrees, or 30 to 60 degrees relative to the central axis.

[0035] The finger opening can be converted into an electrical measurement value by a linear variable displacement transducer of the multi-finger caliper tool 52. In the collapsed configuration, the finger array 56 can be positioned close to the body portion 54. To transition to the extended configuration, the finger array 56 can extend radially from the body portion 54. In the extended configuration, the finger array 56 contacts the inner surface of the wellbore 18 and generates a measurement value indicating the inner surface of a portion of the wellbore 18. As the multi-finger caliper tool 52 extends longitudinally along the wellbore 18 in the axial direction of movement, the measurement value typically changes in response to variations in the inner surface, including variations in the overall diameter and variations caused by surface defects such as protrusions, grooves, cracks, holes, corrosion, etc.

[0036] The movement of the multi-finger caliper tool 52 can be controlled by a component located on the surface of the hydrocarbon field 10. For example, this component may include a winch positioned outside the wellbore 18. It is understood that the discussion of the movement of the multi-finger caliper tool 52 through and / or through a portion of the wellbore 18 can refer to the component-controlled movement of the multi-finger caliper tool 52 within the wellbore 18.

[0037] In light of the foregoing, the multi-finger caliper tool 52 can perform one or more passes through the wellbore 18 in an extended configuration of the finger array 56 in the axial direction (e.g., a first axial direction and / or an opposite second axial direction). For example, when the multi-finger caliper tool 52 traverses the wellbore 18, the finger array 56 can scan the inner surface of the wellbore 18 and generate electrical measurements indicating the radius of the wellbore 18. For example, the first finger array 56A can generate a first set of measurements for a portion of the wellbore 18, while the second finger array 56B can generate a second set of measurements for a portion of the wellbore 18. Therefore, the multi-finger caliper tool 52 can generate two sets of measurements for the same portion of the wellbore 18.

[0038] In some cases, the multi-finger caliper tool 52 can perform one or more passes through portions of the wellbore 18 (e.g., the section of interest within the tubing, casing, and / or liner of the wellbore 18). The multi-finger caliper tool 52 can pass through the section of interest at various speeds to generate additional sets of measurements. In other cases, different multi-finger caliper tools 52 can perform passes through portions of the wellbore 18 (e.g., the section of interest) to generate additional sets of measurements. Increasing the number of measurements can improve robustness and / or improve the reliability of interpretation and / or the various properties of the wellbore determined by the interpretation system 50.

[0039] The multi-finger caliper tool 52 can transmit measured values ​​(e.g., a first set of measured values, a second set of measured values) to the interpretation system 50. The interpretation system 50 may include any suitable computing device, cloud computing device, etc., and may include various components that perform various analytical operations. Figure 2 As shown, the interpretation system 50 may include a processor 58, a memory 60, a storage unit 62, a display 64, etc. The processor 58 may be any type of computer processor or microprocessor capable of executing computer-executable code. The memory 60 and storage unit 62 may be any suitable article of art that can be used as a medium for storing processor-executable code, data, etc. For example, the memory 60 and / or storage unit 62 may store one or more models (e.g., algorithms, machine learning models), relationships, or both, that can be used to interpret measurements from the multi-finger caliper tool 52. In another example, the memory 60 and / or storage unit 62 may store previous interpretations executed by the processor 58 and / or measurements from the multi-finger caliper tool 52. These articles of art may represent a non-transient computer-readable medium (i.e., any suitable form of memory or storage device) capable of storing processor-executable code used by the processor 58 to execute the techniques currently disclosed. The memory 60 and storage unit 62 may also be used to store data received via I / O ports, data analyzed by the processor 58, etc.

[0040] Display 64 may include any type of electronic display, such as a fluidic crystal display, a light-emitting diode display, etc. Thus, data acquired via the I / O port and / or data analyzed by the processor 58 can be presented on display 64, allowing interpretation system 50 to present production datasets related to the operation of hydrocarbon field 10 for viewing. In some embodiments, display 64 may be a touchscreen display or any other type of display capable of receiving input from an operator. Although interpretation system 50 is described as including... Figure 2 The components presented in the system, but the interpretation system 50 should not be limited to including Figure 2 The components listed above. In practice, the interpretation system 50 may include more or fewer components than those listed above. In some embodiments, the interpretation system 50 may be described as a processor-based monitoring and analysis system, a control system or controller, or any combination thereof. The interpretation system 50 may be integrated into a system for... Figure 1 The main control system of the hydrocarbon field 10 is within and / or connected to the system for... Figure 1 The main control system of the hydrocarbon field 10 is such that the measurements from the multi-point caliper tool 52 can be used to control various devices (e.g., valves, pumps, compressors, separators, downhole tools, etc.) to improve the operation of the hydrocarbon field 10.

[0041] In light of the foregoing, the interpretation system 50 can adjust the measurements from the multi-finger caliper tool 52 without user intervention. For example, the interpretation system 50 can convert the electrical measurements from the multi-finger caliper tool 52 into radius values ​​based on at least one model (e.g., a first model) indicating the corresponding relationships generated during the calibration process. Using this model, the interpretation system 50 can also reduce or eliminate the original measurement errors introduced by the multi-finger caliper tool 52, such as errors arising from tool limitations and / or operational aspects. For example, tool limitations may include one or more broken fingers of the first finger array 56A and / or the second finger array 56B. In another example, operational aspects may include a scattered tool and / or an misaligned tool (e.g., the multi-finger caliper tool 52 is offset or decentered relative to its central axis). Additionally or alternatively, the interpretation system 50 may apply a model indicating an elliptical shape (e.g., a second model) to remove outliers from the first set of measurements and / or the second set of measurements. Therefore, the interpretation system 50 can apply this model to adjust the measurements from the multi-finger caliper tool 52 to generate a correction radius value corresponding to the measurements. For example, the interpretation system 50 can generate a first set of correction radius values ​​based on a first set of measurements from the first finger array 56A, and a second set of correction radius values ​​based on a second set of measurements from the second finger array 56B.

[0042] Using correction radius values, interpretation system 50 can identify one or more defects within a portion of wellbore 18. For example, interpretation system 50 can generate a defect map based on the correction radius values ​​(e.g., mapping defects relative to their axial position along the central axis of wellbore 18 and in a circumferential direction around the central axis). Interpretation system 50 can identify defects within the inner surface of that portion of wellbore 18 based on image processing techniques and defect maps. In other cases, interpretation system 50 can identify defects based on variations between absolute correction radius values. Interpretation system 50 can determine the severity of a defect based on its depth (e.g., radial depth), length, width, location, or any combination thereof. In some cases, interpretation system 50 can identify multiple defects within a portion of wellbore 18. Interpretation system 50 can group defects together based on the relative distance between each defect and / or a third model indicating mechanical and / or stress considerations. Interpretation system 50 can score various defects and defect groups on a severity scale (e.g., increasing severity from 1 to 10, 1 to 100, etc.). In some embodiments, close spacing (e.g., less than a threshold spacing) between multiple defects can increase the score of a set of defects. In some embodiments, close spacing (e.g., less than a threshold spacing) between one or more defects and structural features (e.g., wellbore connections or flanges, side ports, seals, etc.) can increase the score of one or more defects. The interpretation system 50 can also identify the repetition frequency of each defect across different multi-finger caliper measurements to examine (e.g., verify) the defects. For example, the interpretation system 50 can identify the repetition frequency between a first set of corrected radius values, a second set of corrected radius values, and one or more sets of stored corrected radius values ​​generated by different multi-finger caliper tools 52, which may be stored in memory 60 and / or storage unit 62.

[0043] Interpretation system 50 can determine the wellbore strength of a portion of wellbore 18 based on defects and a model (e.g., a third model) indicating mechanical and / or stress considerations. In some cases, the model may include industry standards regarding wellbore strength, grouping defects, etc. For example, interpretation system 50 can determine the amount of pressure a defective portion of wellbore 18 can withstand. Interpretation system 50 can also generate and output corrosion analysis of wellbore 18 based on adjusted radius values ​​and threshold radius values. For example, interpretation system 50 can generate and output corrosion analysis of a portion of wellbore 18 based on comparisons between a first set of measurements from the first finger array 56A to identify corrosion thickness, corrosion length, corrosion percentage, etc., on the inner surface of wellbore 18. For example, interpretation system 50 can output a summary table of corrosion levels (e.g., status) and / or properties for each drill collar and joint with wellbore. Corrosion levels may include the percentage of corrosion, corrosion thickness, corrosion length, etc. These properties may include minimum inner diameter, maximum drilling progress, etc.

[0044] In some cases, the interpretation system 50 can also identify and merge measurements from different multi-finger caliper tools 52. Measurements can be correlated with portions of the wellbore 18 and generated under different conditions. The interpretation system 50 can align the measurements in depth and / or azimuth, and then merge the measurements to generate composite measurements with enhanced resolution (e.g., high resolution). The interpretation system 50 can then identify defects, wellbore strength, corrosion, etc., within portions of the wellbore 18 based on the composite measurements.

[0045] The interpretation system 50 can instruct the display 64 to output defect maps, corrosion analysis, wellbore strength, repeatability index, etc. For example, the interpretation system 50 can identify and output the segment of interest corresponding to the portion of wellbore 18 with a corrosion level greater than the threshold corrosion level and / or a wellbore strength less than the threshold wellbore strength. Figure 4 As shown, the interpretation system 50 can output visual indications via the graphical user interface (GUI) 139 of the electronic display, including the correction radius value, the relative changes between correction radius values, the defect map, and the changes in the number of defects along the depth. The interpretation system 50 can also output one or more buttons prompting the user for input. These buttons may include a first button indicating the start of production operation, a second button indicating the continuation of production operation, a third button indicating adjustments to the production operation, a fourth button indicating the saving of measurement values, etc.

[0046] In some cases, the interpretation system 50 can instruct the operation of one or more components within the hydrocarbon field 10 based on defect maps and / or various properties of the wellbore. For example, the interpretation system 50 can instruct one or more components of the hydrocarbon field 10 to initiate or continue production operations in response to determining that the corrosion level is less than a threshold corrosion level and / or the wellbore strength is greater than a threshold wellbore strength. In another example, the interpretation system 50 can instruct one or more components of the hydrocarbon field 10 to perform corrective actions in response to determining that the corrosion level is greater than a threshold corrosion level and / or the wellbore strength is less than a threshold wellbore strength. For example, the interpretation system 50 can instruct one or more components of the hydrocarbon field 10 to remove or repair a portion of the wellbore 18 as a corrective action. In another example, the interpretation system 50 can instruct one or more components (e.g., welding tools, surface coating tools, repair or plugging tools, etc.) to repair that portion of the wellbore 18 as a corrective action. Corrective actions may also include actions such as removing a portion of the wellbore 18 in response to determining that the severity of a defect is greater than a threshold severity, injecting cement into a portion of the wellbore 18 in response to identifying a leak point, etc. In other examples, the interpretation system 50 may instruct production operations to cease for a period of time as a corrective action and adjust tools within the wellbore 18, for example, by instructing one or more tools to be positioned in or removed from the wellbore 18. In some embodiments, the interpretation system 50 may directly and / or indirectly control (e.g., via a processor-based controller) one or more valves, pumps, compressors, chemical injection systems, downhole tools, surface tools and equipment, or any combination thereof, based on defect maps and / or various characteristics of the wellbore.

[0047] In some cases, the interpretation system 50 can implement machine learning techniques and / or artificial intelligence to interpret measurements and output predictive analyses. For example, memory 60 and / or storage component 62 can store machine learning models that can be trained based on “training data” indicating different use cases and / or measurements from the multi-finger caliper tool 52. The model can also be trained based on measurements from the multi-finger caliper tool 52 and / or interpretations performed by the interpretation system 50 over time. Therefore, the interpretation system 50 can implement machine learning techniques and / or artificial intelligence to adjust measurements from the multi-finger caliper tool 52 to generate a corrected radius value, identify one or more defects based on the corrected radius value, determine wellbore strength, determine the severity of defects, determine corrosion levels, identify drill collars of wellbore 18, etc. In another example, the interpretation system 50 can implement machine learning techniques and / or artificial intelligence to perform corrosion analysis on that portion of wellbore 18 based on measurements from the multi-finger caliper tool 52. In another example, the interpretation system 50 may implement machine learning techniques and / or artificial intelligence to identify measurements from different multi-finger caliper tools, align measurements, and generate composite measurements. In some embodiments, the interpretation system 50 may analyze measurements obtained from the multi-finger caliper tool 52 at multiple different times (e.g., days, weeks, months, or years), identify trends in the wellbore 18 (e.g., trends in defects, structural integrity, etc.), generate predictions of the future health and / or failures of the wellbore 18, schedule future maintenance (e.g., repairs, replacements, etc.), and generate control parameters (e.g., changing the flow rate or operating characteristics of the wellbore) that can extend the life of the wellbore 18 until it can be maintained.

[0048] although Figure 2 The example shown includes a multi-finger caliper tool 52, but it is understood that the interpretation system 50 can be communicatively coupled to more than one multi-finger caliper tool 52 and receive measurements from each multi-finger caliper tool 52 indicating at least a portion of the inner surface of the wellbore 18.

[0049] Figure 3 A flowchart is shown of operating the multi-finger caliper tool 52 and interpreting the measurements from the multi-finger caliper tool 52 via the interpretation system 50. For example, the interpretation system 50 can interpret the measurements to generate and / or output a picture (e.g., a surface image) indicating a portion of the inner surface of the wellbore 18, identify one or more defects within that portion of the wellbore 18, identify the section of interest, and so on.

[0050] At box 90, the interpretation system 50 can receive measurements from the multi-finger caliper tool 52. For example, the interpretation system 50 can receive a first set of measurements for a portion of the wellbore 18 from the first finger array 56A of the multi-finger caliper tool 52, and a second set of measurements for a portion of the wellbore 18 from the second finger array 56B. Alternatively, the interpretation system 50 can receive multiple sets of measurements from different multi-finger caliper tools 52 located within corresponding portions of the wellbore 18. As discussed herein, the interpretation system 50 can convert electrical measurements from the multi-finger caliper tool 52 into radius values ​​using at least one model stored in memory 60 and / or storage unit 62.

[0051] Models can be generated during at least one of the following calibration steps: master tool calibration (box 92), pre-operation calibration (box 94), and post-operation calibration (box 96). At box 92, the interpretation system 50 can instruct the multi-finger caliper tool 52 to traverse different pipes of known diameters at various temperatures to calibrate the multi-finger caliper tool 52. The multi-finger caliper tool 52 can generate electrical measurements by converting finger opening (e.g., extension) into electrical measurements via a linear variable displacement transducer coupled to each finger. The conversion from displacement to electrical measurements can be performed at various temperatures to account for the transducer's temperature sensitivity. The interpretation system 50 can generate at least one model indicating the relationship between the electrical measurements and the different radius values ​​generated during the master tool calibration step. For example, the master tool calibration step (box 92) can occur during the manufacture of the multi-finger caliper tool 52 before deployment to a specific location (e.g., hydrocarbon site 10) for measurement.

[0052] At box 94, the interpretation system 50 can perform pre-operation calibration of the multi-finger caliper tool 52. For example, the interpretation system 50 can instruct the multi-finger caliper tool 52 to pass through different pipes of known diameters at surface and / or ambient temperatures to calibrate the multi-finger caliper tool 52 before operating it within the wellbore 18. In some embodiments, the pre-operation calibration of the multi-finger caliper tool 52 can be performed immediately before a measurement run in the wellbore 18, such as immediately following a week, several days, and / or several hours prior to the measurement run. The interpretation system 50 can compare measurements generated during the pre-operation calibration step with measurements from a standard tool calibration step to identify variations in electrical measurements. The interpretation system 50 can generate at least one model indicating the relationship between electrical measurements and different radius values ​​generated during the pre-operation calibration step. At least one model can include coefficients generated based on measurements from pre-operation calibration and (if available) post-operation correction. For example, the interpretation system 50 can determine the gain and / or offset to be applied to the measurement and store the variations in the model. Interpretation system 50 can use this model to focus measurements generated by the multi-finger caliper tool 52 by applying gain and / or offset. The model may include linear regression, where the relationship between the corrected measurement radius and the known diameter of the different rings is considered an affine function. Additionally or alternatively, the model may include higher-order polynomial functions. In some cases, interpretation system 50 may use fitting methods to adjust the measurements and / or fit the measurements to a model generated during the pre-operation calibration step. Therefore, interpretation system 50 can calibrate the measurements for any variations in the transducer and / or fingers of the multi-finger caliper tool 52 that may occur between the time of master tool calibration and the time of pre-operation calibration.

[0053] At box 96, the interpretation system 50 can perform post-operation calibration of the multi-finger caliper tool 52. The interpretation system 50 can instruct the multi-finger caliper tool 52 to pass through pipes of known diameters at ambient temperature to calibrate the multi-finger caliper tool 52 in a manner similar to the pre-operation calibration step after operation within the wellbore 18. In some embodiments, the post-operation calibration of the multi-finger caliper tool 52 can be performed immediately after a measurement run in the wellbore 18, such as immediately after a week, several days, and / or several hours. The interpretation system 50 can generate at least one model indicating the relationship between electrical measurements generated during the post-operation calibration step and different radius values, the difference between electrical measurements generated during the post-operation calibration step and the pre-operation calibration step, or both. The model may include coefficients generated based on measurements from the pre-operation calibration and post-operation calibration. Alternatively, the interpretation system 50 can identify wear on one or more fingers of the multi-finger caliper tool 52, which may be caused by rough conditions within the wellbore 18, based on changes in post-operation corrected measurements and pre-operation corrected measurements. The interpretation system 50 can store the identifiers of the worn fingers in a model.

[0054] At box 98, interpretation system 50 can perform drill collar detection based on measurements received at box 90. For example, interpretation system 50 can identify drill collars of wellbore 18 based on diameter variations within the measurements. Drill collars can be associated with connections between sections of wellbore 18, and therefore drill collars can include annular bodies, flanges, or connection structures that differ from the connection sections of wellbore 18 (e.g., diameter variations). Drill collars can be identified based on diameters greater than a threshold diameter. The threshold diameter can include the diameter of a straight portion of wellbore 18, and the drill collar can include a joint of wellbore 18. Interpretation system 50 can output a table of the status of each drill collar including the measured portion of wellbore 18. This status can include the diameter of the drill collar and / or a comparison between the diameter of the drill collar and the threshold diameter. In some cases, interpretation system 50 can combine measurements from multi-finger caliper tool 52 and one or more tools within hydrocarbon field 10 to identify joints.

[0055] At box 100, interpretation system 50 can generate and output corrosion statistics based on measurements received at box 90 and drill collar detection at box 98. For example, interpretation system 50 can determine the corrosion level based on a comparison between the diameter of wellbore 18 and a threshold diameter. Interpretation system 50 can generate corrosion statistics based on changes in measurements and / or comparisons. Interpretation system 50 can output a table of drill collars (e.g., wellbore joints) with wellbore 18 and their corresponding corrosion levels. This table may also include statistics indicating wellbore 18, such as minimum inner diameter, maximum drilling progress, etc. Interpretation system 50 can also identify sections of interest that include one or more drill collars with corrosion levels greater than a threshold corrosion level. In some cases, interpretation system 50 can instruct one or more components of hydrocarbon field 10 to repair portions of wellbore 18 corresponding to sections of interest. Interpretation system 50 can instruct multi-finger caliper tool 52 to perform a pass through the section of interest after repair. The interpretation system 50 can respond to a corrosion level greater than a corrosion threshold by instructing one or more components of the hydrocarbon field 10 to initiate production operations at a corrosion level less than the corrosion threshold at the layer of interest and / or instructing one or more components to perform additional repairs at the layer of interest.

[0056] At box 102, the interpretation system 50 can adjust the measurements received at box 90 from the multi-finger caliper tool 52 to generate a corrected radius value. For example, a damaged or faulty finger of the multi-finger caliper tool 52 may introduce tool limitations, which could lead to erroneous measurements. For example, a finger may include a broken segment, a bent segment, a worn segment (e.g., a tip), a faulty joint (e.g., a pivot joint that cannot rotate the finger properly), or any combination thereof. In another example, the multi-finger caliper tool 52 may not be centered relative to the central axis of the wellbore 18, thus introducing errors into the measurements. Thus, the interpretation system 50 can apply adjustments to the measurements to reduce or eliminate measurement errors introduced by or from the multi-finger caliper tool 52 or by its operation. Additionally or alternatively, the interpretation system 50 may convert electrical measurements into radius values ​​and / or adjust the measurements based on a model generated during pre-operation calibration steps and / or post-operation calibration steps. For example, interpretation system 50 can adjust measured values ​​by applying gain and / or offset values ​​generated during the pre-operation calibration step, and / or adjust measured values ​​generated by one or more fingers having wear as determined in the post-operation calibration step. Interpretation system 50 can also perform adjustments using one or more models discussed below.

[0057] In some cases, coefficients can be used to calculate the correction radius value. During real-time processing of measurements from the multi-finger caliper tool 52, a post-operation calibration step may not be performed, and the interpretation system 50 can use coefficients from the pre-operation calibration step to calculate the correction radius value. During post-operation processing, the interpretation system can combine coefficients from the pre-operation and post-operation calibration steps to generate a combined coefficient set for calculating the correction radius value.

[0058] For example, the interpretation system 50 can input radius values ​​into a model (e.g., a second model) to identify and remove outliers from the radius values. This model can describe the finger position relative to the location of the multi-finger caliper tool 52 within the wellbore 18. The model can represent the inner bore of the wellbore 18 as an elliptical shape. The elliptical shape can be represented by Equation 1 below.

[0059] (Equation 1)

[0060] Therefore, the solution to the least squares minimization problem shown in Equation 2 can be achieved using data points. Fit an ellipse.

[0061] (Equation 2)

[0062] in It is a vector of coefficients of a second-order polynomial, and It is a matrix formed by data points. To account for the existence of potentially malfunctioning fingers of the multi-finger caliper tool 52, the model can include additional constraints in the minimization problem, and to keep their number low without predefined values, the model can include the constraints shown in Equation 3. Regularization term.

[0063] (Equation 3)

[0064] in This is an elliptical bias caused by a faulty finger. The bias can be limited to account for specific cases, such as the negative value of an unopened finger as shown in Equation 4.

[0065] (Equation 4)

[0066] The model can include a bias as a solution to the minimization problem, where the bias can be a given real number. The model can include robust statistical methods for labeling (binarization step) and generating a list of faulty fingers. The model can exclude measurements from faulty fingers from further calculations. Thus, the interpretation system 50 can identify outliers in the radius values ​​caused by broken and / or faulty fingers of the multi-finger caliper tool 52 based on the model described in Equations 1-4. The interpretation system 50 can exclude outliers (e.g., radius variations) from corrected radius values ​​and / or interpretations, such as those related to... Figure 5 Further described. Therefore, the interpretation system 50 can generate correction radius values ​​based on measurements from box 90 and / or from the master tool calibration step, pre-operation calibration step, post-operation calibration step, ellipse model, or any combination thereof.

[0067] In other cases, the interpretation system 50 can adjust the radius value based on changes in the correction radius value. For example, the interpretation system 50 can perform finger offset correction, which adjusts for the deviation between the average value of each azimuth and the overall average value of all azimuth measurements. As used herein, "azimuth measurement value" can include measurements in the circumferential direction around the central axis of the borehole 18. For example, the interpretation system 50 can subtract the average radius value of all azimuths from the radius value of each azimuth. Thus, the interpretation system 50 can generate relative radius variation data, such as... Figure 4 As shown, it can highlight defects. In another example, the interpretation system 50 can automatically generate individual defect maps for different multi-finger caliper tools 52 based on relative radius variation data, such as... Figure 4 As shown. Based on the defect detection map, the interpretation system 50 can calculate the total number and intensity of defect pixels at each depth. Thus, the interpretation system 50 provides a quantification tool to evaluate the quality of each depth to be included in the finger offset estimation. Based on the defect variations along the depth image, the interpretation system 50 can automatically identify the depth intervals used to estimate the finger offset deviation. Within the selected depths, the interpretation system 50 can ignore defect points during the finger offset deviation calculation and use only non-defect points to estimate the finger offset deviation for each azimuth angle.

[0068] At box 104, the interpretation system 50 can be based on Figure 6The steps illustrated in the diagram are used to perform alignment defect detection. For example, the interpretation system 50 aligns a first set of measurements from the first finger array 56A and a second set of measurements from the second finger array 56B based on depth, radius, and / or azimuth. Alternatively, the interpretation system 50 may receive additional sets of measurements indicating portions of the wellbore 18 from different multi-finger caliper tools 52 and align the first or second set of measurements with the additional set of measurements based on depth, radius, and / or azimuth. The interpretation system 50 can use the aligned measurements to detect defects within portions of the wellbore 18.

[0069] At box 106, the interpretation system 50 can identify the repetition frequency of each defect in multiple measurements from different multi-finger caliper tools 52 based on the extracted defects, such as... Figure 6 and 7 As shown. For example, interpretation system 50 can identify defects within a first set of measurements and verify defects within a second set of measurements. In another example, interpretation system 50 can identify defects within the first set of measurements and / or the second set of measurements and verify measurements within an additional set of measurements. If interpretation system 50 identifies a defect within the second set of measurements and / or the additional set of measurements, interpretation system 50 can verify the defect. The repetition of defects in different sets of measurements can be an indicator of the reliability of the measurements. Regarding... Figure 6 and 7 The process for defect detection and defect repeatability index is further described. If the interpretation system 50 does not identify a defect within the second set of measurements and / or the additional set of measurements, the interpretation system 50 may instruct different multi-finger caliper tools 52 to perform measurements through the portion of the wellbore 18 corresponding to the defect and generate measurements. The interpretation system 50 can use the measurements to verify the defect.

[0070] At box 108, the interpretation system 50 can perform a caliper merging step to generate composite measurements indicating that portion of the wellbore 18. For example, the interpretation system 50 can retrieve multiple multi-finger caliper tool measurements indicating the same portion of the wellbore 18 and generated (e.g., acquired) under different conditions (e.g., temperature). For example, the interpretation system 50 can align multiple multi-finger caliper tool measurements in depth and azimuth. The interpretation system 50 can then merge (e.g., combine) the measurements to generate composite measurements indicating the portion of the wellbore 18 (e.g., aggregate representation), which can provide higher resolution measurements and / or reduce or eliminate the effects of outliers and / or erroneous measurements. For example, the interpretation system 50 can retrieve two multi-finger caliper tool measurements that can be generated at different times by a multi-finger caliper tool 52 with 40 fingers, and merge the two multi-finger caliper tool measurements to generate a composite image with 80-finger resolution. Thus, composite measurements provide higher resolution measurements (e.g., higher resolution images) compared to individual multi-finger caliper tool measurements. To generate composite measurements, the interpretation system 50 can average multiple values ​​at a pixel value into a single representative value and / or use a weighted average.

[0071] At box 110, the interpretation system 50 can identify defects within the composite measurement. For example, the interpretation system 50 can identify defects by detecting changes in the absolute radius value by applying a defect detection method to extract relative changes from the absolute radius data of the composite multi-finger caliper measurement.

[0072] At box 112, interpretation system 50 can group one or more defects together and characterize one or more defects. When several defects are detected, their contribution to reducing wellbore strength varies based on their relative distance from each other. Interpretation system 50 can group defects based on a model that indicates consideration of mechanical stress interactions (e.g., a third model). This model can be based on industry standards.

[0073] At box 114, the interpretation system 50 can estimate the strength of that portion of the wellbore 18 based on the defects identified in boxes 110 and 112. For example, the interpretation system 50 can output predefined tables, finite element analyses, 3D descriptions of the wellbore, etc. The interpretation system 50 can also determine the severity of a defect based on its geometry (e.g., depth, length, shape, volume, etc.), location, etc. The severity of the defect can also be based at least in part on the material used for the wellbore 18, the diameter of the wellbore 18, the wall thickness of the wellbore 18, the age of the wellbore 18, normal operating conditions in the wellbore 18 (e.g., pressure, flow rate, fluid composition, etc.), or any combination thereof. If the severity of the defect exceeds a threshold severity, the interpretation system 50 can instruct and / or control one or more tools (e.g., welding tools, repair tools, coating tools, cementing tools, etc.) to repair the defective portion of the wellbore 18. Interpretation system 50 may instruct one or more components of hydrocarbon field 10 to cease and / or delay production operations until that portion of wellbore 18 can be repaired. If the severity of the defect is less than a threshold severity, interpretation system 50 may instruct one or more components of hydrocarbon field 10 to initiate production operations.

[0074] Figure 4 The presentation is shown Figure 2 The graphical user interface (GUI) 139 is generated by the interpretation system. The GUI includes a first graph 140 indicating the correction radius, a second graph 142 indicating the relative change of the correction radius, a third graph 144 indicating the defect map, and a fourth graph 146 indicating the number of defects.

[0075] The first graphic 140 is a visual indication of the corrected radius value of a portion of the wellbore 18. The first graphic 140 can show variations in the inner surface of the portion of the wellbore 18 as a function of image intensity (e.g., as a function of grayscale or as a function of color). The horizontal axis of the first graphic 140 represents the circumferential or azimuthal direction around the central axis of the wellbore 18, while the vertical axis of the first graphic 140 represents the axial direction along the central axis of the wellbore 18. Image intensity (e.g., grayscale or color) can indicate relative changes in radius (e.g., variations), relative highs and lows (e.g., peaks and valleys) within the inner surface, etc. Therefore, the interpretation system 50 can provide a visual indication of the internal portion of a portion of the wellbore. Alternatively or additionally, the interpretation system 50 can use the corrected radius value to perform drill collar inspection steps (box 98) and / or determine the level of corrosion within a portion of the wellbore 18.

[0076] The second graph 142 shows the relative change in the correction radius value as a function of image intensity (e.g., grayscale or color). Similar to the first graph 140, the horizontal axis of the second graph 142 represents the circumferential or azimuth direction around the central axis of the borehole 18, while the vertical axis of the second graph 142 represents the axial direction along the central axis of the borehole 18. For example, the interpretation system 50 can generate the relative change by subtracting the average radius value of all azimuths from the radius value of each azimuth. In this way, the difference between each radius value and the average radius value can be determined and displayed. The difference can be displayed on the second graph 142 in the corresponding image intensity (e.g., grayscale or color). In some cases, a larger difference can provide a better indication of a defect compared to a smaller difference.

[0077] The third graphic 144 illustrates multiple defects 148 within a portion of the borehole 18 as a function of image intensity (e.g., grayscale or color). Similar to the first graphic 140, the horizontal axis of the third graphic 144 represents the circumferential or azimuthal direction around the central axis of the borehole 18, while the vertical axis of the third graphic 144 represents the axial direction along the central axis of the borehole 18. The interpretation system 50 can identify areas in the third graphic 144 that exhibit significant variations in depth, single-point variations relative to the surrounding background, etc. For example, the first defect 148A may include a defect caused by axial tool scraping or chiseling of the inner surface of the borehole 18, the second defect 148B may include a single-point defect caused by corrosion, and / or the third defect 148C may include a single-point defect. As shown, the first defect 148A typically extends axially along the central axis of the borehole 18, but the first defect 148A also rotates or angles as it moves axially due to the rotational movement of the tool within the borehole. The depth variation within the third graphic 144 can be represented as a function of image intensity (e.g., grayscale or color). For example, regions with depth variations can be represented by a first image intensity (e.g., grayscale or color), and regions without depth variations can be represented by a second image intensity (e.g., grayscale or color). As shown, the first defect 148A, the second defect 148B, and / or the third defect 148C are indicated by the first image intensity (e.g., grayscale or color), while the surrounding background is indicated by the second image intensity (e.g., grayscale or color). The interpretation system 50 can use image processing techniques to identify the first defect 148A, the second defect 148B, and / or the third defect 148C in the third graphic 144. Additionally or alternatively, the interpretation system 50 can identify defects based on regions in the third graphic 144 that have significant depth variations, single-point variations relative to the surrounding background, etc. The interpretation system 50 can also determine the severity of the defect 148 by determining the length, width, depth, etc. of the defect 148.

[0078] The fourth graph 146 illustrates the variation in the number of defects with respect to depth. The fourth graph 146 shows the number of defects (horizontal axis) along the axial length (e.g., vertical axis) of this portion of the wellbore 18. For example, if the wellbore 18 represents a wellbore (e.g., casing, tubing, liner, etc.), then the fourth graph 146 shows the number of defects on the horizontal axis as a function of depth on the vertical axis. The interpretation system 50 can generate the fourth graph 146 by determining the total number and intensity of defect pixels at each depth based on the third graph 144. In this way, the interpretation system 50 can provide quantitative tools to evaluate the quality of each depth used for finger offset estimation (e.g., finger offset correction). Based on the variation in defects, the interpretation system 50 can automatically identify the depth intervals used to estimate finger offset deviations.

[0079] Figure 5 A first elliptical model 180 and a second elliptical model 182, according to embodiments of the present disclosure, are shown that can be used by the interpretation system 50 to determine various characteristics of a wellbore 18. The interpretation system 50 can adjust the radius value based on the model indicating the elliptical shape of the bore of the wellbore 18. Although the ideal geometry of the bore can be circular or cylindrical, the bore of the wellbore 18 can be elliptical due to manufacturing defects, forces applied to the wellbore 18, or other factors. Therefore, by modeling the bore of the wellbore 18 as elliptical, the interpretation system 50 can more accurately identify defects (e.g., protrusions, grooves, cracks, holes, corrosion, etc.) in the bore of the wellbore 18. For example, the interpretation system 50 can center and / or fit the radius value to the model representing the elliptical shape to determine the center of the position of the multi-finger caliper tool 52 relative to the multi-finger caliper tool 52 within the wellbore 18.

[0080] Considering the foregoing, the first ellipse model 180 shows the radius values ​​fitted to a standard ellipse shape, and the second ellipse model 182 shows the radius values ​​fitted to a modified ellipse shape. As shown, line 184 illustrates the fitted shapes of the respective ellipse models 180 and 182, and point 186 indicates the radius values ​​(e.g., measurement points) from the multi-finger caliper tool 52. The fitted shape may include an estimated wellbore diameter. For example, each point 186 may represent a radius value measured by the corresponding finger of the multi-finger caliper tool 52.

[0081] The radius value may not fit the first elliptical model 180. As shown, the radius value can extend beyond the fitted shape of the first elliptical model 180, which may be due to finger misalignment, errors in the linear variable displacement transducer, and / or other tool limitations. Additionally, as shown, the two fingers of the multi-finger caliper tool 52 may produce anomalous measurements as indicated by points 188 and 190. These anomalous measurements can bias the fitted measurements to outliers, introducing errors into the corrected radius value.

[0082] As shown in the second elliptic model 182, the residuals of the shape fitted to the radius values ​​can be extended to defect errors within the radius values. For example, the second elliptic model 182 can utilize thresholding (e.g., filtering) to detect radius values ​​larger than a threshold radius value (e.g., nominal radius, ellipticized radius). The second elliptic model 182 can remove detected radius values ​​from the fitted measurements, which can reduce or eliminate errors introduced by tool limitations. The second elliptic model 182 can also utilize a combination of geometric distance errors applied to circles or ellipses and robust loss functions used for least-squares fitting methods to reduce or eliminate errors. Additionally or alternatively, the interpretation system 50 can perform comparisons of multiple independent fits to the second elliptic model 182 to generate a bad finger probability map. Using the bad finger probability map, the interpretation system 50 can identify damaged and / or faulty fingers in multi-finger caliper tools because the likelihood of repeated erroneous radius values ​​between images is low.

[0083] Figure 6 A flowchart of example method 230 is shown, which aligns measurements from a multi-finger caliper tool 52 and identifies defects and / or the frequency of defect repetition based on measurements from an interpretation system 50. The interpretation system 50 can assess defect repetition by comparing measurements from different multi-finger caliper tools 52. Repetition of defects across measurements can indicate the reliability of the measurements and verify the defects.

[0084] At box 232, the interpretation system 50 can receive a first set of measurements from the first multi-finger caliper tool 52 and a second set of measurements from the second multi-finger caliper tool 52.

[0085] At box 234, the interpretation system 50 can generate a first corrected radius value and a second corrected radius value based on a first set of measurements and a second set of radius values. To this end, the interpretation system 50 can base its calculations on... Figure 3 (Box 102) Discusses the automatic calibration steps to adjust the first set of measurements and the second set of measurements. In another example, the interpretation system 50 may perform finger offset correction to generate a correction radius value.

[0086] At box 236, the interpretation system 50 can generate aligned first and second correction radius values ​​by shifting the first and second correction radius values. The interpretation system 50 can adjust the first and / or second correction radius values ​​using depth shift, radius shift, and / or azimuth shift to adjust for differences between the multi-finger caliper tools 52. For example, the first correction radius value can be offset in radius, depth, and / or azimuth to align with the second correction radius value. In another example, the second correction radius value can be offset in radius, depth, and / or azimuth to align with the first correction radius value. Therefore, radius values ​​from different multi-finger caliper tools can be compared. Furthermore, the interpretation system 50 can reduce or eliminate measurement errors caused by operational factors and / or tool differences.

[0087] At box 238, the interpretation system 50 can extract the relative change from the first correction radius value and the second correction radius value. The interpretation system 50 can convert the aligned first correction radius value and / or the aligned second correction radius value into a format that highlights the defect. For example, the interpretation system 50 can remove local background to highlight the relative change between the aligned first correction radius value and / or the aligned second correction radius value. The interpretation system 50 can identify the relative change between the aligned first correction radius value and the aligned second correction radius value, such as... Figure 4 As shown. In another example, the interpretation system 50 can identify outliers and / or exclude radius variations by fitting the aligned first correction radius value and / or the aligned second correction radius value to the model (e.g., the second model, the second elliptical model 182).

[0088] At box 240, the interpretation system 50 can identify defects within a portion of the wellbore 18 based on a first aligned correction radius value and a second aligned correction radius value. For example, the interpretation system 50 can automatically identify relative radius variation data based on the first aligned correction radius value and the second aligned correction radius value, and identify defects based on the radius variation data. In another example, the interpretation system 50 can generate individual defect maps based on the first aligned correction radius value and the second aligned correction radius value, such as... Figure 7 As shown. The interpretation system 50 can determine the repetition of defects after identifying them. In other words, the interpretation system 50 can generate a first defect map based on measurements from a first multi-finger caliper tool 52, and a second defect map based on measurements from a second multi-finger caliper tool 52. The interpretation system 50 can identify defects based on the defect maps by detecting single-point changes relative to the surrounding background or by using image processing techniques. Additionally or alternatively, the interpretation system 50 can match defect overlap between different multi-finger caliper tools by examining each spatial location (e.g., depth, azimuth) of the defect map within a predetermined distance tolerance.

[0089] Method 230 will be described as being executed by the interpreter system 50; however, it should be noted that any suitable processor-based device can be specifically programmed to perform any step of the method described herein. It should be understood that the steps of method 230 may not be executed in the specific order shown. Furthermore, it should be understood that method 230 described below may include… Figure 6 The interpretation system 50 may output some or all of the steps described herein. For example, the interpretation system 50 may output a GUI on an electronic display indicating a defect, a first correction radius value, a second correction radius value, a first correction radius value for alignment, a second correction radius value for alignment, or any combination thereof. In another example, the interpretation system 50 may instruct one or more components of the hydrocarbon field 10 to perform actions based on the identified defect. In this way, the interpretation system 50 may adjust production operations based on the identified defect.

[0090] Figure 7 A GUI 309 is shown presenting the output generated by the interpretation system 50. The GUI 309 includes a first defect map 310, a second defect map 312, and a defect repetition map 314. The horizontal axes of the first defect map 310, the second defect map 312, and the defect repetition map 314 represent the circumferential or azimuthal direction about the central axis of the wellbore 18, while the vertical axes of the first defect map 310, the second defect map 312, and the defect repetition map 314 represent the axial direction (e.g., depth) along the central axis of the wellbore 18. As discussed herein, the interpretation system 50 can generate the first defect map 310 based on measurements from the first multi-finger caliper tool 52, and the second defect map 312 based on measurements from the second multi-finger caliper tool 52. The first defect map 310 and / or the second defect map 312 can show similarities to those about... Figure 4 The third figure 144 described has several defects 318.

[0091] The interpretation system 50 can generate a defect repetition map 314 based on the first defect map 310 and the second defect map 312. The defect repetition map 314 can illustrate the repetition frequency associated with each defect. The GUI 309 can include a legend 316 indicating the number of repetitions as a function of image intensity (e.g., grayscale or color). For example, if a defect is identified in N defect maps, the interpretation system 50 can set the repetition index of that defect to N. As shown, a defect 318 can be identified in two different defect maps 310 and 312. Thus, the defect repetition map 314 can illustrate defect 318 corresponding to an image intensity (e.g., grayscale or color) of N=2.

[0092] The technical effects of the disclosed embodiments include interpreting measurements from one or more multi-finger caliper tools to determine various parameters related to production operations in a well within a hydrocarbon field. For example, the disclosed embodiments may receive measurements from one or more multi-finger caliper tools, which may include erroneous measurements introduced by tool limitations and / or operational aspects. The disclosed embodiments may adjust measurements based on one or more models (e.g., computer models), align measurements from different multi-finger caliper tools, etc., to generate a correction radius value. The disclosed embodiments may identify one or more defects within the wellbore based on the correction radius value. If multiple defects are identified, the disclosed embodiments may group and characterize the defects based on a model indicative of industry standards (e.g., a computer model), and determine wellbore strength based on the grouped defects. If the wellbore strength is below a threshold wellbore strength, the disclosed embodiments may stop and / or delay production operations within the hydrocarbon field and instruct one or more components to operate (e.g., repair) on a portion of the wellbore associated with the defect. If the wellbore strength is above the threshold wellbore strength, the disclosed embodiments may instruct one or more components to initiate or maintain production operations. In some cases, the disclosed embodiments may receive multiple measurements from different multi-finger caliper tools and identify the repetition frequency of defects across each of the measurements. In other cases, the disclosed embodiments may combine measurements to generate composite measurements with improved resolution compared to individual measurements. Alternatively or additionally, the disclosed embodiments may use the measurements to identify drill collars within the wellbore and determine the level of corrosion in the wellbore. If the corrosion level is greater than a threshold corrosion level, the disclosed embodiments may instruct one or more components to operate on a portion of the wellbore associated with the defect. If the corrosion level is less than the threshold corrosion level, the disclosed embodiments may instruct one or more components to initiate or maintain production operations. Thus, the disclosed embodiments can improve production operations by refining the determination of various characteristics of the wellbore.

[0093] The subject matter described in detail above may be defined by one or more clauses, as follows.

[0094] In one embodiment, a system may include: a multi-finger caliper tool configured to be positioned within a wellbore (e.g., casing, tubing, and / or liner) of a hydrocarbon field, wherein the multi-finger caliper tool is configured to generate measurements indicating the inner surface of the wellbore; a component coupled to the multi-finger caliper tool and configured to adjust the position of the multi-finger caliper tool within the wellbore; and a computing system communicatively coupled to the multi-finger caliper tool. The computing system may include processing circuitry and a memory storing instructions. When executed by the processing circuitry, the instructions may cause the processing circuitry to perform an autonomous workflow to instruct the component to adjust the position of the multi-finger caliper tool within the wellbore to generate the measurements, convert the measurements into radius values ​​based on at least one of a plurality of models, and generate a corrected radius value based on the radius value and a second of the plurality of models. When executed by the processing circuitry, the instructions may also cause the processing circuitry to generate a defect map indicating a portion of the wellbore based on the corrected radius value and instruct a display to show the defect map.

[0095] According to the system described in the foregoing clauses, the instructions, when executed by the processing circuit, cause the processing circuit to identify one or more defects in a portion of the wellbore based on the defect map, group the one or more defects based on a third model among the plurality of models, and determine the wellbore strength of a portion of the wellbore based on the one or more defects.

[0096] According to any of the foregoing clauses, in a system where, when the processing circuit executes an instruction, the instruction causes the processing circuit to instruct one or more tools to operate on a portion of the wellbore in response to determining that the wellbore strength is less than a threshold wellbore strength.

[0097] According to any of the foregoing clauses, in a system where, when the processing circuit executes an instruction, the instruction causes the processing circuit to instruct the multi-finger caliper tool to generate additional measurements by passing through a portion of the wellbore corresponding to one or more defects.

[0098] According to the system described in the foregoing clauses, the instructions, when executed by the processing circuit, cause the processing circuit to: convert the additional measurement value into an additional radius value based on the at least one model; generate an additional corrected radius value based on the additional radius value and a second model; generate an additional defect map indicating a portion of the wellbore based on the additional corrected radius value; generate a defect repetition map based on a comparison between the defect map and the additional defect map; and instruct the display to show the defect map, the additional defect map, and the defect repetition map.

[0099] According to the system described in the foregoing clause, wherein the instructions, when executed by the processing circuitry, cause the processing circuitry to identify one or more additional defects based on the additional correction radius value and to determine the repetition frequency of the one or more defects based on a comparison between the one or more defects and the one or more additional defects, wherein the defect repetition map contains an indication of the repetition frequency.

[0100] According to any one of the foregoing clauses, the system wherein the instructions, when executed by the processing circuit, cause the processing circuit to generate the at least one model in such a way as to: generate a first model of the at least one model by instructing the component to adjust the multi-finger caliper tool to a second position within one or more pipes having a known diameter, the first model indicating a first relationship between electrical measurements and corresponding diameters at various temperatures; generate a second model of the at least one model by instructing the component to adjust the multi-finger caliper tool to a third position within one or more pipes having a known diameter before generating the measurements, the second model indicating a second relationship between the electrical measurements and corresponding diameters at ambient temperature; and generate a third model of the at least one model by instructing the component to adjust the multi-finger caliper tool to a fourth position within one or more pipes having a known diameter after generating the measurements, the third model indicating a third relationship between the electrical measurements and corresponding diameters at ambient temperature.

[0101] According to the system described in the foregoing clause, when the processing circuit executes instructions, the instructions cause the processing circuit to generate a corrected radius value by fitting the radius value to an elliptical model, removing outliers from the radius value based on the fit, and identifying one or more faulty fingers of the multi-finger caliper tool based on the outliers.

[0102] In one embodiment, the method may include, via processing circuitry, a multi-finger caliper tool passing through the wellbore of a hydrocarbon well site; instructing components of the hydrocarbon well site to adjust the position of the multi-finger caliper tool within the wellbore to generate a set of measurements; receiving from the multi-finger caliper tool a set of measurements indicating the inner surface of a portion of the wellbore; and converting the set of measurements into a set of radius values ​​based on at least one of a plurality of models. The method may further include, via processing circuitry, generating a set of corrected radius values ​​based on the set of radius values ​​and a second model of the plurality of models; and via processing circuitry, generating a defect map indicating the portion of the wellbore based on the set of corrected radius values. The method may further include, via processing circuitry, identifying one or more defects within the portion of the wellbore based on the defect map; and via processing circuitry, instructing a display to show a graphic including the set of corrected radius values ​​and the defect map.

[0103] The method as described in the foregoing clauses includes: instructing the components, via the processing circuit, to adjust the position of the multi-finger caliper tool through a pipe of known diameter at ambient temperature to generate a first set of calibration data; instructing the components, via the processing circuit, to adjust the position of the multi-finger caliper tool through a pipe of known diameter at ambient temperature to generate a second set of calibration data; instructing the multi-finger caliper tool, via the processing circuit, to generate the second set of calibration data by traversing through a pipe of known diameter at ambient temperature; determining a plurality of gains and offsets, via the processing circuit, based on a comparison between the first set of calibration data and stored calibration data, and a comparison between the second set of calibration data and stored calibration data; and applying the plurality of gains and offsets, via the processing circuit, after converting the set of measurements into the set of radius values.

[0104] The method according to any of the preceding clauses includes: receiving, via processing circuitry, a second set of measurements of the inner surface of a portion of the wellbore indicated by a second multi-finger caliper tool, wherein the second multi-finger caliper tool is controlled by the component; converting the second set of measurements into a second set of radius values ​​based on at least one model via processing circuitry; generating a second set of corrected radius values ​​based on the second set of radius values ​​and a second model via processing circuitry; and aligning the set of corrected radius values ​​and the second set of corrected radius values ​​in depth, radius, azimuth, or any combination thereof via processing circuitry.

[0105] The method according to the foregoing provisions includes, via processing circuitry, identifying changes in a second set of correction radius values; via processing circuitry, identifying one or more additional defects based on the changes; and via processing circuitry, verifying a first defect among the one or more defects based on the one or more additional defects.

[0106] The method according to the foregoing clauses includes, in response to the verification, incrementing the defect frequency of the first defect via the processing circuit, and generating a defect repetition map including an indication of the defect frequency of the first defect via the processing circuit.

[0107] The method according to any of the foregoing clauses includes determining the wellbore strength of a portion of the wellbore based on grouping one or more defects and a third model among a plurality of models via processing circuitry, and in response to determining that the wellbore strength is less than a threshold wellbore strength, instructing one or more tools to operate on the portion of the wellbore via processing circuitry.

[0108] In one embodiment, a system may include: a multi-finger caliper tool configured to be positioned within a wellbore in a hydrocarbon field, wherein the multi-finger caliper tool is configured to generate measurements indicating the inner surface of the wellbore; a component coupled to the multi-finger caliper tool and configured to adjust the position of the multi-finger caliper tool; and a computing system communicatively coupled to the multi-finger caliper tool. The computing system may include processing circuitry and a memory storing instructions. When executed by the processing circuitry, the instructions may cause the processing circuitry to perform an autonomous workflow to perform a first calibration of the multi-finger caliper tool by instructing the component to adjust the position of the multi-finger caliper tool through one or more pipes of known diameter to generate a first calibration measurement as it passes through one or more pipes; instructing the component to adjust the position of the multi-finger caliper tool within the wellbore to generate a measurement as it passes through the wellbore; and instructing the component to adjust the position of the multi-finger caliper tool through one or more pipes of known diameter to generate a second calibration measurement as it passes through one or more pipes. When executed by the processing circuit, the instruction can cause the processing circuit to convert the measured value into a radius value based on a first calibration measurement value, a second calibration measurement value, and at least one of multiple models, generate a corrected radius value based on the second model among the multiple models, generate a defect map indicating a portion of the wellbore based on the corrected radius value, and instruct the display to show the defect map.

[0109] In the system of the foregoing embodiment, when the processing circuit executes an instruction, the instruction causes the processing circuit to identify the position of the drill collar in the wellbore based on the measurement value, identify a subset of measurement values ​​related to the straight portion of the wellbore based on the position of the drill collar, convert the subset of measurement values ​​into a subset of radius values ​​based on at least one model, determine the corrosion level of the straight portion of the wellbore based on a comparison between the subset of radius values ​​and a threshold radius value, and instruct the display to show the corrosion level.

[0110] In the system of the foregoing embodiment, when the processing circuit executes an instruction, the instruction causes the processing circuit to instruct one or more tools to operate on a portion of the wellbore in response to determining that the corrosion level is greater than a threshold corrosion threshold.

[0111] According to any of the foregoing embodiments of the system, wherein the instructions, when executed by the processing circuit, cause the processing circuit to retrieve one or more additional measurements indicating the inner surface of the wellbore from a database, generate a composite measurement indicating the inner surface of the wellbore by combining the one or more additional measurements and the measurement, and identify one or more defects on the inner surface of the wellbore based on the composite measurement.

[0112] According to any of the foregoing embodiments of the system, wherein the instructions, when executed by the processing circuitry, cause the processing circuitry to group the one or more defects based on the relative distance between each of the one or more defects, determine the wellbore strength based on the grouping of the one or more defects and a third model, and in response to determining that the wellbore strength is less than a threshold wellbore strength, instruct one or more tools to operate on a portion of the wellbore.

[0113] For purposes of explanation, the foregoing description has been given by reference to specific embodiments. However, the illustrative discussion above is not intended to be exhaustive or to limit this disclosure to the precise forms disclosed. In view of the foregoing teachings, many modifications and variations are possible. Furthermore, the order of elements illustrating and describing the methods described herein may be rearranged, and / or two or more elements may occur simultaneously. The embodiments were chosen and described in order to best explain the principles of this disclosure and its practical application, thereby enabling others skilled in the art to best utilize this disclosure and various embodiments with various modifications suitable for the intended particular use.

[0114] Finally, the techniques proposed and claimed herein are referenced and applied to material objects and specific examples of practical characteristics that significantly improve the field of expertise and are therefore not abstract, intangible, or purely theoretical. Furthermore, if any claim appended to the end of this specification contains one or more elements designated as “means for [performing]…[function]…” or “steps for [performing]…[function]…”, such elements are intended to be interpreted according to 35U.SC112(f). However, for any claim containing elements designated in any other manner, such elements are not intended to be interpreted according to 35U.SC112(f).

Claims

1. A system comprising: A multi-finger caliper tool, the multi-finger caliper tool being configured to be positioned within a wellbore in a hydrocarbon field, wherein the multi-finger caliper tool is configured to generate measurements indicating the inner surface of the wellbore; A component, the component being connected to the multi-finger caliper tool and configured to adjust the position of the multi-finger caliper tool within the wellbore; and A computing system communicatively connected to the multi-finger caliper tool, the computing system comprising: Processing circuits; and A memory for storing instructions, wherein the instructions, when executed by the processing circuitry, cause the processing circuitry to perform an autonomous workflow to: The component is instructed to adjust the position of the multi-finger caliper tool within the wellbore to generate the measurement value; The measured value is converted into a radius value based on at least one of multiple models; A corrected radius value is generated based on the radius value and the second model among the plurality of models; A defect map indicating a portion of the wellbore is generated based on the corrected radius value; and The indicator displays the defect diagram.

2. The system of claim 1, wherein the instructions, when executed by the processing circuit, cause the processing circuit to: Based on the defect map, identify one or more defects in a portion of the wellbore; The one or more defects are grouped based on a third model among the multiple models; and The wellbore strength of a portion of the wellbore is determined based on one or more of the defects.

3. The system of claim 2, wherein the instructions, when executed by the processing circuit, cause the processing circuit to: In response to determining that the wellbore strength is less than a threshold wellbore strength, one or more tools are instructed to operate on a portion of the wellbore.

4. The system of claim 2, wherein the instructions, when executed by the processing circuit, cause the processing circuit to: The multi-finger caliper tool is instructed to generate additional measurements by traversing a portion of the wellbore corresponding to one or more defects.

5. The system of claim 4, wherein the instructions, when executed by the processing circuit, cause the processing circuit to: Based on the at least one model, the additional measurement value is converted into an additional radius value; An additional correction radius value is generated based on the additional radius value and the second model; An additional defect map indicating a portion of the wellbore is generated based on the additional correction radius value; A defect repetition map is generated based on a comparison between the defect map and the additional defect map; and The display is instructed to show the defect diagram, the additional defect diagram, and the defect repetition diagram.

6. The system of claim 5, wherein the instructions, when executed by the processing circuit, cause the processing circuit to: One or more additional defects are identified based on the additional correction radius value; and The repetition frequency of the one or more defects is determined based on a comparison between the one or more defects and the one or more additional defects, wherein the defect repetition map contains an indication of the repetition frequency.

7. The system of claim 1, wherein the instructions, when executed by the processing circuit, cause the processing circuit to generate the at least one model in the following manner: The first model of the at least one model is generated by instructing the component to adjust the multi-finger caliper tool to a second position within one or more pipes having a known diameter. The first model indicates a first relationship between electrical measurements and the corresponding diameter at various temperatures. By instructing the component to adjust the multi-finger caliper tool to a third position within one or more pipes of a known diameter before generating the measurement value, a second model of the at least one model is generated, the second model indicating a second relationship between the electrical measurement value and the corresponding diameter at ambient temperature; and A third model is generated from the at least one model by instructing the component to adjust the multi-finger caliper tool to a fourth position within one or more pipes of a known diameter after the measurement is generated. The third model indicates a third relationship between the electrical measurement and the corresponding diameter at the ambient temperature.

8. The system of claim 7, wherein the instructions, when executed by the processing circuit, cause the processing circuit to: One or more gain values ​​and / or one or more offset values ​​are identified based on a comparison between a first model and a second model in the at least one model, a comparison between a first model and a third model in the at least one model, or a comparison between both; and The one or more gain values ​​and / or the one or more offset values ​​are applied to the radius value to generate the corrected radius value.

9. The system of claim 1, wherein the second model comprises an elliptical model, and wherein the instructions, when executed by the processing circuitry, cause the processing circuitry to generate the correction radius value in such a manner as follows: Fit the radius value to the ellipse model; Based on the fitted values, outliers are removed from the radius values; and Based on the outliers, one or more faulty fingers of the multi-finger caliper tool are identified.

10. A method comprising: The processing circuit instructs the components at the hydrocarbon well site to adjust the position of the multi-finger caliper tool within the wellbore to generate a set of measurements. The processing circuitry receives a set of measurements from the multi-finger caliper tool that indicate a portion of the inner surface of the wellbore. The processing circuit converts the set of measurements into a set of radius values ​​based on at least one of a plurality of models. The processing circuit generates a set of corrected radius values ​​based on the set of radius values ​​and the second model among the plurality of models. The processing circuit generates a defect map indicating a portion of the wellbore based on the set of correction radius values. The processing circuit identifies one or more defects within a portion of the wellbore based on the defect map. and The processing circuitry instructs the display to show a graphic including the set of correction radius values ​​and the defect map.

11. The method of claim 10, comprising: The processing circuit instructs the components to adjust the position of the multi-finger caliper tool as it passes through a pipe of known diameter at ambient temperature to generate a first set of calibration data. The processing circuit instructs the components to adjust the position of the multi-finger caliper tool as it passes through a pipe of known diameter at the ambient temperature to generate a second set of calibration data. Multiple gains and offsets are determined by the processing circuit based on a comparison between the first set of calibration data and the stored calibration data, and a comparison between the second set of calibration data and the stored calibration data. and After converting the set of measurements into the set of radius values ​​via the processing circuitry, the plurality of gains and offsets are applied.

12. The method of claim 10, comprising: A second set of measurements indicating the inner surface of a portion of the wellbore is received from the second multi-finger caliper tool via a processing circuit, wherein the second multi-finger caliper tool is controlled by the component; The processing circuit converts the second set of measurements into a second set of radius values ​​based on the at least one model. The processing circuit generates a second set of corrected radius values ​​based on the second set of radius values ​​and the second model. and The processing circuit aligns the first set of correction radius values ​​and the second set of correction radius values ​​in terms of depth, radius, azimuth, or any combination thereof.

13. The method of claim 12, comprising: The processing circuit identifies changes in the second set of correction radius values. One or more additional defects are identified based on the changes via the processing circuitry. and The first defect among the one or more defects is verified based on the one or more additional defects via the processing circuit.

14. The method of claim 13, comprising: In response to the verification, the defect frequency of the first defect is increased via the processing circuit. and The processing circuit generates a defect repetition map, which includes an indication of the defect frequency of the first defect.

15. The method of claim 10, comprising: The wellbore strength of a portion of the wellbore is determined via the processing circuit based on grouping the one or more defects and a third model among the plurality of models; and In response to determining that the wellbore strength is less than a threshold wellbore strength, the processing circuit instructs one or more tools to operate on a portion of the wellbore.

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