System and method for ranging and tracking while drilling multiple geologic wells

Abstract

A system includes a first rotary steerable tool configured to control a first drill bit to drill a first well having a first wellbore trajectory. The first rotary steerable tool includes: a first orientation and tilt assembly including a first set of sensors configured to detect a static magnetic field; and a signal source configured to generate a source signal. The system also includes a second rotary steerable tool configured to control a second drill bit to simultaneously drill a second well having a second wellbore trajectory that follows the first wellbore trajectory. The second rotary steerable tool includes a second orientation and tilt assembly including a second set of sensors configured to detect the source signal.

Description

Cross-reference paragraphs

[0001] This application claims the benefit of U.S. nonprovisional application No. 18 / 502,111, filed November 6, 2023, entitled “SYSTEMS AND METHODS FOR RANGING AND TRACKING WHILE DRILLING MULTIPLE GEOLOGICAL WELLS”, the disclosure of which is incorporated herein by reference. Background Technology

[0002] This disclosure generally relates to ranging and tracking. More specifically, this disclosure relates to simultaneously drilling two geological wells with the same orientation at a constant distance between two geological wells using ranging and tracking.

[0003] This section aims to introduce the reader to various aspects of the technology that may be related to the aspects of this disclosure, which are described and / or claimed below. It is believed that this discussion will help provide the reader with background information to better understand the aspects of this disclosure. Therefore, it should be understood that these statements should be interpreted in this context and are not intended as an admission of prior art.

[0004] Geothermal energy refers to the generation of energy using the internal heat of the Earth's crust. The generation of geothermal energy involves drilling wells into the Earth's crust. Wells allow for the extraction of heat using various methods (e.g., using hot water and steam). Geothermal energy can be used to heat homes and buildings. For example, hot water can be circulated through a heat exchanger that transfers geothermal heat to homes and buildings. Additionally or alternatively, geothermal energy can be used to generate electricity (e.g., in geothermal power plants). For example, electricity can be generated when geothermal energy produces steam that drives a turbine in a generator. Geothermal energy is a renewable and sustainable form of energy because it uses natural heat from the Earth to generate electricity.

[0005] In some applications, it may be desirable to drill multiple geological wells (e.g., geothermal wells) with similar but offset trajectories through geological formations. Therefore, systems and methods are needed for automatically ranging and tracking wells drilled simultaneously in geological formations. Summary of the Invention

[0006] The following provides an overview of some of the embodiments disclosed herein. It should be understood that these aspects are presented only to provide the reader with a brief overview of these specific 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.

[0007] Some embodiments of this disclosure include a system comprising a first rotary steerable tool configured to control a first drill bit to drill a first well having a first well path. The first rotary steerable tool includes: a first orientation and tilt assembly including a first set of sensors configured to detect a static magnetic field; and a signal source configured to generate a source signal. The system also includes a second rotary steerable tool configured to control a second drill bit to simultaneously drill a second well having a second well path that follows the first well path. The second rotary steerable tool includes a second orientation and tilt assembly including a second set of sensors configured to detect the source signal.

[0008] Some embodiments of this disclosure include a system comprising a second rotary steerable tool configured to control a second drill bit to simultaneously drill a second well having a second wellbore trajectory that follows a first wellbore trajectory of a first well being drilled by a first drill bit controlled by the first rotary steerable tool. The first rotary steerable tool includes: a first orientation and tilt assembly including a first set of sensors configured to detect a static magnetic field; and a signal source configured to generate a source signal. The second rotary steerable tool includes a second orientation and tilt assembly including a second set of sensors configured to detect the source signal.

[0009] Some embodiments of this disclosure include a method comprising: operating a first rotary steerable tool to control a first drill bit to drill a first well having a first wellbore trajectory. The first rotary steerable tool includes: a first orientation and tilt assembly including a first set of sensors configured to detect a static magnetic field; and a signal source configured to generate a source signal. The method further includes: operating a second rotary steerable tool to control a second drill bit to simultaneously drill a second well having a second wellbore trajectory that follows the first wellbore trajectory. The second rotary steerable tool includes a second orientation and tilt assembly including a second set of sensors configured to detect the source signal.

[0010] Various modifications to the foregoing features may exist with respect to various aspects of this disclosure. Additional features may also be incorporated into these aspects. These modifications and additional features may exist individually or in any combination. For example, the various features discussed below with respect 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 background of embodiments of this disclosure and does not limit the claimed subject matter. Attached Figure Description

[0011] A better understanding of the various aspects of this disclosure can be achieved after reading the following detailed description and referring to the accompanying drawings, in which: Figure 1 This is a schematic diagram of a geological survey of two wells drilled simultaneously according to the implementation scheme of this disclosure; Figure 2 It is based on the implementation scheme of this disclosure that can be used to determine Figure 1 A schematic diagram of the coordinate system for the orientation and orientation of each of the two wells; Figure 3 This is a schematic diagram of a tracked tool (i.e., the tool being tracked) according to an embodiment of the present disclosure, the tracked tool having a source for emitting signals, which can be emitted by a sensor of a tracking tool (i.e., the tool tracking another tool). Figure 1 During the geological survey, detection was conducted; and Figure 4 It is based on the implementation scheme of this disclosure. Figure 3 Example diagrams of tracked and tracking tools with different components, which can be used to determine the relative position between two drilling tools during geological surveys. Detailed Implementation

[0012] The following summarizes some 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.

[0013] When describing elements of various embodiments of the invention, the articles “a,” “an,” “the,” and “the” are intended to mean one or more of the elements present. The terms “comprising,” “including,” and “having” are used in an open-ended manner and should therefore be construed as meaning “including, but not limited to.” Furthermore, any use of the terms “connected,” “joined,” “attached,” “attached,” or any other term describing the interaction between elements is intended to mean an indirect or direct interaction between the described elements. Additionally, as used herein, the terms “axial” and “axially” generally mean along or parallel to a central axis (e.g., the central axis of a body or port), while the terms “radial” and “radially” generally mean perpendicular to the central axis. For example, axial distance refers to a distance measured along or parallel to the central axis, and radial distance refers to a distance measured perpendicular to the central axis. The use of “top,” “bottom,” “above,” “below,” and variations of these terms is for convenience and does not require any particular orientation of the components.

[0014] Throughout the specification and claims, certain terms are used to refer to specific features or components. As those skilled in the art will understand, different people may use different names to refer to the same feature or component. This document is not intended to distinguish between components or features that have different names but the same function.

[0015] Geological wells (e.g., geothermal wells) are drilled in areas containing reservoirs (e.g., intermediate-temperature geothermal reservoirs with temperatures ranging from 150 to 180 degrees Celsius). For example, in a dual-well geological survey, a main well (e.g., a horizontally extended reach well) can be drilled along a planned well trajectory. Additionally, an auxiliary well (e.g., a tracker well) can be drilled simultaneously along an auxiliary well trajectory parallel to the main well trajectory, maintaining a constant distance between the main and auxiliary well trajectories. During drilling operations, the main and auxiliary wells can monitor and track each other until the two well trajectories intersect at the target location (e.g., at a target depth within the reservoir).

[0016] Such simultaneous and parallel drilling operations can provide geothermal energy harvesting with improved drilling efficiency and reduced drilling costs. In contrast, other geothermal drilling operations may include drilling a main well in the region, and drilling auxiliary wells at different times that follow the wellbore trajectory of the main well. These separate drilling operations may result in increased drilling time and additional monitoring / tracking tools to ensure that the auxiliary wellbore trajectories drilled at different times follow the existing main wellbore trajectory.

[0017] The aforementioned simultaneous and parallel drilling operations may rely on accurate distance measurement and tracking of direction, orientation, and the relative distance between two drilling systems / tools used to drill two wells during geological surveys. This disclosure provides systems and methods for tracking the relative positions between two simultaneously drilled geological wells in real time and adjusting drilling operations to maintain the trajectories of the two wellbores in the same drilling direction at a fixed distance (e.g., a constant distance) relative to each other.

[0018] For example, during geological surveys, a tracked tool, including an energy source (e.g., a magnetic source, seismic source, electromagnetic source, acoustic or sound source), can be used to drill a tracked well in the area. The energy source can generate signals, such as magnetic signals, seismic signals, electromagnetic signals, or other suitable signals. A tracked tool, including sensors or sensor arrays, can be used to drill a tracked well in the area simultaneously with drilling the tracked well. The tracked tool can use sensors or sensor arrays disposed within the tracked tool to detect signals emitted from the energy source disposed within the tracked tool. Based on the detected signals, the tracked tool can perform data processing, such as analyzing the detected signals, determining direction, determining orientation, and determining distance relative to the tracked tool. Using the results of the data processing (e.g., the determined relative direction, orientation, and distance), the tracked tool can (e.g., using a rotary steering system (RSS) controlled by rolling-stabilized electronics) adjust certain operations (e.g., adjusting the drilling direction) so that the wellbore trajectory of the tracked well follows the wellbore trajectory of the tracked well. In this way, the tracking tool can track the movement of the tracked tool in real time, resulting in two geological wells being drilled simultaneously and in parallel at a constant distance from each other.

[0019] Considering the foregoing, let's now turn to the attached diagram. Figure 1 This is a schematic diagram of a geological survey using two wells drilled simultaneously in a region. Well 10 is drilled from platform 12 (e.g., an inland or offshore platform) located in the region. The region may include surface 20 (e.g., the surface of the earth or the ocean surface) and multiple subsurface layers, such as subsurface layers 22, 24, and 26 located at different depths relative to surface 20. Well 10 may be drilled vertically or substantially vertically through some shallow subsurface layers (e.g., subsurface layers 22 and 24). At a certain depth, for example, when approaching subsurface layer 26 which includes a reservoir (e.g., a geothermal reservoir), the drilling direction may gradually change to a horizontal or substantially horizontal direction (e.g., generally parallel to surface 20), thereby forming a wellbore trajectory 14 (e.g., the trajectory of the well being drilled). Wellbore trajectory 14 may include substantially vertical sections and substantially horizontal sections.

[0020] Simultaneously, well 16 is drilled from platform 18 located in the area (e.g., an inland or offshore platform). Well 16 may be drilled vertically or substantially vertically through shallow subsurface layers (such as subsurface layers 22 and 24). As it approaches subsurface layer 26, the drilling direction may gradually change to a horizontal or substantially horizontal direction (e.g., generally parallel to surface 20), thereby forming a wellbore trajectory 30 (e.g., the trajectory of the well being drilled). Wellbore trajectory 30 may include substantially vertical and substantially horizontal portions. At an intersection 50 (e.g., at a target depth 52 in the reservoir located in subsurface layer 26), wellbore trajectory 30 intersects with wellbore trajectory 14 at the corresponding substantially horizontal portions, thereby allowing geothermal fluids (e.g., water, steam, or other suitable fluids) to circulate and generate natural flow due to temperature gradients and changes in fluid density.

[0021] During the simultaneous drilling of wells 10 and 16, certain ranging and tracking systems and tools can be used to automatically monitor and adjust the drilling process so that the wellbore trajectory 30 of well 16 follows the wellbore trajectory 14 of well 10. For example, well 10 can be drilled using a tracked tool (e.g., a bottom hole assembly (BHA1)). BHA1 may include a rotary steerable system controlled by a rolling stabilizer.

[0022] The rotary steerable system provides guidance and navigation to control the drill bit to drill Well 10 based on the planned wellbore trajectory. Steering and navigation can utilize direction and inclination (D&I) technology (e.g., PowerDrive) to infer the drilling direction and inclination via Earth's gravity and magnetic field. The rotary steerable system can be driven by a rolling stabilizer to stabilize BHA1 to avoid accidental sidetracking and / or vibrations to maintain the quality of the well 10 being drilled.

[0023] BHA1 may also include a direction and tilt (D&I) module. The D&I module may include sensors (e.g., a magnetometer) to detect the direction and tilt of BHA1 relative to the Earth's magnetic field. Based on the detected direction and tilt, the rotary steering system can adjust drilling operations to keep the wellbore trajectory 14 following the planned wellbore path.

[0024] Furthermore, BHA1 may include an energy source (e.g., a permanent magnet) capable of generating signals (e.g., magnetic signals). The signals can be transmitted through the subsurface and reach the tracking tool used to drill well 16. The tracking tool can detect and analyze the signals to determine its relative position to BHA1. Based on the relative position, the tracking tool can perform certain adjustments (e.g., changing the drilling direction, changing the tool orientation) such that the wellbore trajectory 30 of well 16 can follow wellbore trajectory 14 at a constant distance.

[0025] For example, the tracking tool (e.g., the bottom hole assembly (BHA2)) may include a rotary steerable system controlled by a rolling stabilizer. The rotary steerable system provides guidance and navigation to control the drill bit to drill a well 16 having a well trajectory 30 that follows the well trajectory 14. The rotary steerable system may be driven by a rolling stabilizer to stabilize the BHA2 to avoid accidental sidetracking and / or vibrations to maintain the quality of the well 16 being drilled.

[0026] BHA2 may also include a direction and tilt (D&I) module. The D&I module may include sensors (e.g., a magnetometer) to detect signals emitted by the energy source of BHA1. BHA2 may include an onboard processor to analyze the detected signals. Analysis may include signal filtering, signal amplification, amplitude calculation, orientation calculation, etc. BHA2 can determine its relative position with respect to BHA1 (e.g., including direction, orientation, and distance). Based on the relative position, the rotary steering system can adjust drilling operations to maintain the wellbore trajectory 30 of well 16 following the wellbore trajectory 14 at a constant distance.

[0027] Further details regarding the use of the tracked tool (i.e., the tool being tracked) and the tracking tool (i.e., the tool tracking another tool) (including BHA1 and BHA2 and their corresponding components (e.g., power sources, sensors)) to automatically range and track wells 10 and 16 during simultaneous drilling will be provided in the following sections. Figures 2 to 4 supply.

[0028] Figure 2 It can be used to determine Figure 1 A schematic diagram of the coordinate system for the orientation and orientation of well 10 or well 16. The coordinate system includes an origin 100 (e.g., the wellhead of well 10 or well 16). Three orthogonal axes, including axis 102 (e.g., along the north direction), axis 104 (e.g., along the east direction), and axis 106 (e.g., along the direction of Earth's gravity), extend from the origin 100 to form the coordinate system.

[0029] Curve 108 starts from the origin 100, extends downwards, and ends at position 110 (e.g., Figure 1 The curve ends at the intersection point 50, where curve 108 can be used to represent the wellbore trajectory (e.g., Figure 1 (Wellbore trajectory 14 of well 10 or wellbore trajectory 30 of well 16). As shown, curve 108, representing the wellbore trajectory, lies in plane 116, which includes axis 106. Plane 116 has an azimuth angle 120° relative to axis 102. Curve 108 has an inclination angle 130° relative to axis 106.

[0030] As described above, during well drilling operations (e.g., well 10 or well 16), drilling tools including a bottomhole assembly (e.g., the tracked tool or tracking tool described above) can be used to generate a wellbore trajectory (e.g., wellbore trajectory 14 or wellbore trajectory 30) represented by curve 108. At a given position 140 along the wellbore trajectory, the bottomhole assembly can utilize sensors (e.g., a magnetometer disposed in the orientation and tilt (D&I) module) to detect the orientation of the bottomhole assembly relative to the Earth's magnetic field parallel to axis 106. Based on the detected orientation, the bottomhole assembly can determine certain drilling parameters, such as azimuth 120 and tilt 130. The bottomhole assembly can utilize a rotary steering system to adjust the drilling direction to keep the wellbore trajectory following the planned wellbore path and reaching position 110.

[0031] Considering the foregoing, Figure 3 This is a schematic diagram of a tracked tool with a signal transmission source, which can be detected by the tracked tool's sensors. Figure 1 During the geological survey, the tracking tool 200 is used to drill well 10 with wellbore trajectory 14. The tracking tool 200 includes a bottom hole assembly 206 (BHA1) which includes a rotary steerable system 208. The rotary steerable system 208 can be driven by a rolling stabilizer to stabilize the bottom hole assembly 206 in order to avoid accidental sidetracking and / or vibration and maintain the quality of the well 10 being drilled.

[0032] The tracked tool 200 also includes a direction and tilt (D&I) module 212. The D&I module 212 may include an energy source 216 (e.g., a magnet) that can generate a magnetic field 218. The magnetic field 218 can be transmitted through the subsurface layers below the surface 20 and reach the tracking tool 220 used to drill a well 16 with a wellbore trajectory 30.

[0033] The tracking tool 220 includes a bottomhole drill string assembly 226 (BHA2) that includes a rotary steerable system 228. The rotary steerable system 228 can be driven by different rolling stabilizers to stabilize the bottomhole drill string assembly 226 in order to avoid accidental sidetracking and / or vibration in order to maintain the quality of the well 30 being drilled.

[0034] To improve the tracking accuracy of the bottom hole assembly 226 with respect to the bottom hole assembly 206, certain arrangements of energy sources and corresponding sensors can be employed to enable real-time data processing of both the bottom hole assembly 206 and the bottom hole assembly 226. For example, certain parameters, such as differences in time-of-flight (e.g., signal travel time) caused by the axial spacing of the sensors, differences in signal amplitude (e.g., amplitude) caused by the azimuth position of the sensors, and tool phase measured by the rotary steering systems 208 and 228, can be combined and processed to improve tracking accuracy. Such additional parameters can provide enhanced relative position determination between the bottom hole assembly 206 and the bottom hole assembly 226.

[0035] Additionally or alternatively, each of bottom hole assembly 206 and bottom hole assembly 226 may include an electromagnetic telemetry module that allows direct communication between the two assemblies. Using the electromagnetic telemetry module, automatic tracking can be achieved without time delays (e.g., caused by sending data to a surface unit on well 10 and linking action commands downlink to well 16).

[0036] With this in mind, the tracking tool 220 also includes a Direction and Inclination (D&I) module 232. The D&I module 232 may include multiple sensors (e.g., magnetometers 240, 242, and 244). The D&I module 232 can utilize the magnetometers 240, 242, and 244 to detect a magnetic field 218 emitted by the energy source 216 of the D&I module 212 in the tracked tool 200. Based on the detected magnetic signal, the D&I module 232 can calculate certain drilling parameters (e.g., azimuth and inclination angles) associated with the position, orientation, and orientation of the tracking tool 220 relative to the tracked tool 200. Based on the drilling parameters, the bottomhole assembly 226 can utilize the rotary steering system 228 to adjust certain operations (e.g., dynamically adjusting the drilling direction), thereby maintaining the wellbore trajectory 30 of well 16 following the wellbore trajectory 14 of well 10 during simultaneous drilling processes (e.g., simultaneous drilling of wellbore trajectories 14 and 30). In this manner, a well 16 having a wellbore trajectory 30 parallel to the wellbore trajectory 14 of well 10 is drilled at a constant distance 260 (e.g., 50 to 70 meters). In some embodiments, wellbore trajectories 14 and 30 may be parallel or substantially parallel, such as within a range of plus or minus 10 degrees to each other. Additionally, in some embodiments, wellbore trajectories 14 and 30 may be separated by a constant or substantially constant distance 260, such as a target distance plus or minus 5%, 10%, or 15% of the target distance and / or a target distance plus or minus 5 meters, 10 meters, or 15 meters.

[0037] Magnetometers 240, 242, and 244 can be axially positioned within the D&I module 232 relative to the central longitudinal axis 264 of the tracking tool 220. For example, magnetometer 242 can be positioned at a distance 266 from magnetometer 240 along the central longitudinal axis 264. Magnetometer 244 can be positioned at a distance 268 from magnetometer 242 along the central longitudinal axis 264.

[0038] Additionally, in a cross-sectional view 270 corresponding to a plane 272 perpendicular to the central longitudinal axis 264 of the tracking tool 220, magnetometers 240, 242, and 244 may be oriented relative to the central longitudinal axis 264 of the tracking tool 220 within the D&I module 232. For example, in cross-sectional view 270, magnetometers 240, 242, and 244 may be equally spaced at circumference 274 (e.g., at an angle of 120 degrees to each other).

[0039] With magnetometers 240, 242, and 244 axially and azimuthally positioned within the D&I module 232 relative to the central longitudinal axis 264 of the tracking tool 220, the amplitude of the signal generated from the magnetometers in response to the detection of the magnetic field 218 can vary based on the axial and azimuthal positions of the magnetometers 240, 242, and 244. The D&I module 232 can use the amplitudes of the signals from the different magnetometers to determine the relative position between the tracked tool 200 and the tracking tool 220. Based on the relative position (e.g., including direction, orientation, and distance), the rotary steering system 228 can cause the bottom hole assembly 226 to adjust its position and orientation to maintain the wellbore trajectory 30 of well 16 following the wellbore trajectory 14 of well 10 during simultaneous drilling operations.

[0040] For example, at reference time 276 (e.g., at time...) t At different times 280 (e.g., at time 280), the magnetometer 240 can detect the magnetic field 218 and generate a signal 278. t + t1 At different times 284 (e.g., at time 284), the magnetometer 242 can detect the magnetic field 218 and generate a signal 282. t + t2 (At the location), the magnetometer 244 can detect the magnetic field 218 and generate a signal 286.

[0041] As shown in the figure, the amplitudes of signals 278, 282, and 286 are different due to the different axial and azimuthal positions of magnetometers 240, 242, and 244 relative to the central longitudinal axis 264 of the tracking tool 220, and the different relative positions of the tracking tool 220 to the tracked tool 200. These different amplitudes can be utilized by a rotary steering system 228, which causes the bottom hole assembly 226 to drill well 16 with a wellbore trajectory 30 parallel to the wellbore trajectory 14 of well 10 at a constant distance 260 (e.g., 50 to 70 meters).

[0042] Although the D&I module 232 in this embodiment includes three sensors (e.g., magnetometers 240, 242, and 244), it should be understood that in other embodiments, the D&I module 232 may include fewer (e.g., two) or more sensors (e.g., more than three sensors, such as four, five, six, or more sensors). For example, the D&I module 232 may include two magnetometers that are axially (e.g., with a distance between them) along the central longitudinal axis 264 of the tracking tool 220 and oriented (e.g., at an angle of 180 degrees to each other) around the central longitudinal axis 264.

[0043] Although the energy source 216 in this embodiment relates to a magnetic source, it should be understood that in some embodiments, the D&I module 212 may include different types of energy sources. In one embodiment, the D&I module 212 may include an omnidirectional source that generates pulse signals. For example, the pulse signal may include electromagnetic pulses (e.g., generated by a custom antenna or electromagnetic telemetry module). In one embodiment, the pulse signal may include seismic pulses that can be generated by a seismic source (e.g., a seismic vibrator). In one embodiment, the pulse signal may include sound or acoustic pulses that can be generated by an acoustic source.

[0044] Considering the foregoing, Figure 4 yes Figure 3 Example diagrams are provided of a tracked tool 200 and a tracking tool 220 with different components, which can be used to determine the relative position between the tracked tool 200 and the tracking tool 220 during geological surveys. The tracked tool 200 for drilling well 10 includes a rotary steering system 208 that controls certain operations of the drill bit 304 (e.g., adjusting the rotation of the drill bit 304 to keep the wellbore trajectory 14 following the planned wellbore path). A rolling stabilizer 306 can be used to control the rotary steering system 208. The rolling stabilizer 306 includes a direction and inclination (D&I) module 308 to control the drilling direction and inclination of well 10. The D&I module 308 may include multiple magnetometers (e.g., three magnetometers positioned at 90-degree angles to each other).

[0045] In some embodiments, the rotary guidance system 208 includes a permanent magnet 312. The permanent magnet 312 can be coupled to the drill bit 304 such that the permanent magnet 312 rotates together with the drill bit 304 in a plane perpendicular to the axis (e.g., the central longitudinal axis) of the tracked tool 200. In some embodiments, the rotary guidance system 208 may include different types of energy sources, such as electromagnetic sources, seismic sources, etc.

[0046] The tracking tool 220 for drilling well 16 includes a rotary steering system 228 that controls certain operations of the drill bit 334 (e.g., adjusting the rotation of the drill bit 334 to keep the wellbore trajectory 30 following the wellbore trajectory 14 of well 10). A rolling stabilizer 336 can be used to control the rotary steering system 228. The rolling stabilizer 336 includes a direction and tilt (D&I) module 338 to control the drilling direction and tilt of well 16. The D&I module 338 may include multiple sensors positioned in different locations and orientations. In some embodiments, the D&I module 338 may include three magnetometers orthogonally arranged (e.g., at 90-degree angles to each other). In some embodiments, the D&I module 338 may include two or more different sensors (e.g., electromagnetic sensors, seismic sensors, sound or acoustic sensors, etc.) arranged axially and azimuthally relative to the central longitudinal axis (e.g., axis 264) of the tracking tool 220.

[0047] During drilling operations of well 10, the D&I module 308 is of the rolling-stable type. As the drill collar of the rotary steering system 208 rotates, the permanent magnet 312 rotates with the drill bit 304, thereby generating a rotating magnetic field. A low-pass filter 350 can be used to filter out the rotating magnetic field, allowing the magnetometer located in the D&I module 308 to detect only the direct current (DC) magnetic field representing the geological survey (e.g., the Earth's magnetic field). Based on the detected direction and inclination relative to the DC magnetic field, the rotary steering system 208 can adjust the drilling operations of well 10 to keep the wellbore trajectory 14 following the planned wellbore path.

[0048] During another operation simultaneously with drilling well 16 at well 10, the D&I module 338 is also a rolling stabilizer. The D&I module 338 can be used to measure various magnetic fields. For example, similar to the D&I module 308 of the tracked tool 200, the D&I module 338 can measure direct current (DC) magnetic fields (e.g., the Earth's magnetic field) representing geological surveys. The D&I module 338 may include a low-pass filter 352 to filter out high-frequency magnetic signals.

[0049] It should be noted that the components described above with respect to the tracked tool 200 and the tracking tool 220 are exemplary components, and the tracked tool 200 and the tracking tool 220 may include additional or fewer components, as shown in the figures. For example, each of the tracked tool 200 and the tracking tool 220 may include a mud telemetry module for transmitting data (e.g., tilt data, azimuth data).

[0050] Additionally or alternatively, the D&I module 338 can measure alternating current (AC) magnetic fields (e.g., a rotating magnetic field generated by the rotating permanent magnet 312). The D&I module 338 may include a bandpass filter 356 to filter out low-frequency magnetic signals and detect only the rotating magnetic field. As previously described, the detected signal (e.g., Figure 3 The amplitude of the signal 278, 282, or 286 is proportional to the distance (e.g., distance 360) between the rotary steering systems 208 and 228. The amplitude difference between the signals measured by the D&I module 338 (e.g., using three magnetometers in an orthogonal arrangement) can be used by the rotary steering system 228 to control the tracked tool 200 to drill well 16 with a wellbore trajectory 30 parallel to the wellbore trajectory 14 of well 10 at a constant distance 260 (e.g., 50 to 70 meters).

[0051] The technical effect of the disclosed implementation is to provide two drilling tools (e.g., a tracked tool and a tracking tool, each comprising a bottomhole drill string assembly) for simultaneously drilling two geological wells (e.g., a tracked well and a tracking well), such that the wellbore trajectory of the tracking well can track the wellbore trajectory of the tracked well during geological (e.g., geothermal) exploration. The tracked tool includes three or more sensors to measure the static magnetic field generated by the Earth. The tracked tool also includes a magnetic source (e.g., a permanent magnet) for generating alternating magnetic signals. The tracking tool includes sensors or a sensor array for detecting the alternating magnetic signals emitted from the magnetic source. Based on the detected signals, the tracking tool uses an onboard processing circuitry system to process the detected signals and determine the direction, orientation, and distance relative to the tracked tool. Based on the determined relative direction, orientation, and distance, the tracking tool uses a rotary steering system controlled by rolling-stabilized electronics to adjust the drilling operation, enabling the tracking tool to track the movement of the tracked tool in real time, resulting in the simultaneous and parallel drilling of two wells at a constant distance from each other until the two wellbore trajectories intersect at a target location in the reservoir.

[0052] The topics described in detail above may be limited by one or more clauses, as set forth below.

[0053] A system includes a second rotary steering tool configured to control a second drill bit to simultaneously drill a second well having a second wellbore trajectory that follows a first wellbore trajectory of a first well being drilled by a first drill bit controlled by the first rotary steering tool. The first rotary steering tool includes: a first orientation and tilting assembly including a first set of sensors configured to detect a static magnetic field; and a permanent magnet coupled to the first drill bit and configured to generate an alternating magnetic field. The second rotary steering tool includes a second orientation and tilting assembly including a second set of sensors configured to detect the alternating magnetic field.

[0054] The system as described in the foregoing clauses, wherein the first well and the second well are geothermal wells.

[0055] As described in any of the preceding clauses, wherein the first well and the second well intersect at a target depth in the geothermal reservoir.

[0056] As described in any of the foregoing clauses, each of the first well and the second well includes a substantially vertical portion and a substantially horizontal portion, wherein the first well and the second well intersect at their respective horizontal portions.

[0057] In any of the preceding clauses of the system, each of the first rotary guide tool and the second rotary guide tool is controlled by a rolling stabilizer.

[0058] The system as described in any of the preceding clauses, wherein a first calculated formation density is used to compensate for a second calculated formation density to obtain a compensated formation density.

[0059] The system as described in any of the foregoing clauses, wherein the first rotary steerable tool is configured to guide and navigate the first drill bit to drill the first well based on a planned wellbore trajectory, and the second rotary steerable tool is configured to guide and navigate the second drill bit to drill the second well based on the first wellbore trajectory.

[0060] The system as described in any of the foregoing clauses, wherein the first set of sensors includes at least three magnetometers.

[0061] The system described in any of the foregoing clauses, wherein the static magnetic field corresponds to the Earth's magnetic field.

[0062] The system as described in any of the foregoing clauses, wherein the second set of sensors includes at least two magnetometers.

[0063] The system as described in any of the foregoing clauses, wherein the at least two magnetometers are axially arranged along the central longitudinal axis of the first rotary guide tool.

[0064] As described in any of the foregoing clauses, the at least two magnetometers are oriented equally along the central longitudinal axis of the first rotary guide tool.

[0065] As described in any of the foregoing clauses, the first rotary guide tool includes a low-pass filter to filter out signals induced by the alternating magnetic field.

[0066] The system as described in any of the foregoing clauses, wherein the second rotary guide tool includes a bandpass filter to filter out signals induced by the static magnetic field.

[0067] The system as described in any of the foregoing clauses includes at least two mud telemetry modules configured to transmit data between the first rotary guide tool and the second rotary guide tool.

[0068] A system includes a second rotary steering tool configured to control a second drill bit to simultaneously drill a second well having a second wellbore trajectory that follows a first wellbore trajectory of a first well being drilled by a first drill bit controlled by the first rotary steering tool. The first rotary steering tool includes: a first orientation and tilting assembly including a first set of sensors configured to detect a static magnetic field; and a permanent magnet coupled to the first drill bit and configured to generate an alternating magnetic field. The second rotary steering tool includes a second orientation and tilting assembly including a second set of sensors configured to detect the alternating magnetic field.

[0069] The system as described in the foregoing clauses, wherein the first wellbore trajectory and the second wellbore trajectory are substantially parallel and separated by a substantially constant distance.

[0070] The system as described in any of the foregoing clauses, wherein the first orientation and tilting component includes an omnidirectional source for generating electromagnetic pulses.

[0071] A method comprising: operating a first rotary steerable tool to control a first drill bit to drill a first well having a first wellbore trajectory. The first rotary steerable tool includes: a first orientation and tilting assembly including a first set of sensors configured to detect a static magnetic field; and a permanent magnet coupled to the first drill bit and configured to generate an alternating magnetic field. The method further comprises: operating a second rotary steerable tool to control a second drill bit to simultaneously drill a second well having a second wellbore trajectory that follows the first wellbore trajectory. The second rotary steerable tool includes a second orientation and tilting assembly including a second set of sensors configured to detect the alternating magnetic field.

[0072] As described in the foregoing clauses, the first wellbore trajectory and the second wellbore trajectory are substantially parallel and separated by a substantially constant distance.

[0073] As described in any of the foregoing clauses, wherein the first direction and tilt component includes a seismic source that generates seismic pulses.

[0074] For purposes of explanation, the foregoing description has been described with reference to specific embodiments. However, the above illustrative discussion is not intended to be exhaustive or to limit this disclosure to the precise form disclosed. In view of the foregoing teachings, many modifications and variations are possible. Furthermore, the order of the elements illustrating and describing the methods described herein may be rearranged, and / or two or more elements may occur simultaneously. The embodiments have been chosen and described in order to best explain the principles of this disclosure and its practical application, thereby allowing others skilled in the art to make optimal use of this disclosure and its various embodiments, with various modifications as appropriate for the particular intended use.

[0075] While only certain features of the invention have been illustrated and described herein, many modifications and variations will occur to those skilled in the art. Therefore, it should be understood that the appended claims are intended to cover all such modifications and variations falling within the true spirit of the invention.

[0076] The techniques proposed and claimed herein are referenced and applied to practical and obvious improvements in the nature of physical and concrete examples in the art, and are therefore not abstract, intangible, or purely theoretical. Furthermore, if any claim appended to this specification contains one or more elements designated as “a component for [performing] [a certain function]…” or “a step for [performing] [a certain function]…”, such elements are intended to be applied in accordance with 35 USC. 112(f) shall be interpreted accordingly. However, for any claim that includes an element specified in any other manner, it is intended not to be in accordance with 35 U.SC. 112(f) Explains this type of element.

Claims

1. A system comprising: A first rotary steerable tool, configured to control a first drill bit to drill a first well having a first wellbore trajectory, wherein the first rotary steerable tool comprises: A first orientation and tilting assembly, the first orientation and tilting assembly including a first set of sensors configured to detect a static magnetic field; and A signal source, configured to generate a source signal; and A second rotary steering tool is configured to control a second drill bit to simultaneously drill a second well with a second wellbore trajectory that follows the first wellbore trajectory. The second rotary steering tool includes a second orientation and tilting assembly, which includes a second set of sensors configured to detect the source signal.

2. The system of claim 1, wherein the signal source includes a permanent magnet coupled to the first drill bit and configured to generate the source signal.

3. The system of claim 1, wherein the first well and the second well are geothermal wells.

4. The system of claim 1, wherein the first well and the second well intersect at a target depth in the reservoir.

5. The system of claim 3, wherein each of the first well and the second well comprises a substantially vertical portion and a substantially horizontal portion, wherein the first well and the second well intersect at their respective substantially horizontal portions.

6. The system of claim 1, wherein each of the first rotary guide tool and the second rotary guide tool is controlled by a rolling stabilizer.

7. The system of claim 5, wherein the first rotary steerable tool is configured to guide and navigate the first drill bit to drill the first well based on a planned wellbore trajectory, and the second rotary steerable tool is configured to guide and navigate the second drill bit to drill the second well based on the first wellbore trajectory.

8. The system of claim 1, wherein the first set of sensors comprises at least three magnetometers.

9. The system of claim 1, wherein the static magnetic field corresponds to the Earth's magnetic field.

10. The system of claim 1, wherein the signal source comprises an electromagnetic source.

11. The system of claim 10, wherein the second set of sensors comprises at least two sensors arranged axially along the central longitudinal axis of the first rotary guide tool, or arranged equally oriented along the central longitudinal axis of the first rotary guide tool.

12. The system of claim 1, wherein the first rotary guide tool includes a low-pass filter to filter out a portion of the source signal induced by the alternating magnetic field.

13. The system of claim 1, wherein the second rotary guide tool includes a bandpass filter to filter out a portion of the source signal induced by the static magnetic field.

14. The system of claim 1, comprising at least two mud telemetry modules configured to transmit data between the first rotary guide tool and the second rotary guide tool.

15. A system comprising: A second rotary steerable tool is configured to control a second drill bit to simultaneously drill a second well with a second wellbore trajectory that follows the first wellbore trajectory of a first well, which is being drilled by a first drill bit controlled by a first rotary steerable tool. The first rotary guide tool includes: a first orientation and tilting assembly, the first orientation and tilting assembly including a first set of sensors configured to detect a static magnetic field; and a signal source configured to generate a source signal; and The second rotary guide tool includes a second orientation and tilting assembly, which includes a second set of sensors configured to detect the source signal.

16. The system of claim 15, wherein the first wellbore trajectory and the second wellbore trajectory are substantially parallel and separated by a substantially constant distance.

17. The system of claim 15, wherein the first orientation and tilting component includes an omnidirectional source for generating electromagnetic pulses.

18. A method comprising: Operating a first rotary steerable tool to control a first drill bit to drill a first well having a first wellbore trajectory, wherein the first rotary steerable tool includes: a first orientation and tilting assembly, the first orientation and tilting assembly including a first set of sensors configured to detect a static magnetic field; and a signal source configured to generate a source signal; and The second rotary steering tool is operated to control the second drill bit to simultaneously drill a second well with a second wellbore trajectory that follows the first wellbore trajectory. The second rotary steering tool includes a second orientation and tilting assembly, which includes a second set of sensors configured to detect the source signal.

19. The method of claim 18, wherein the first wellbore trajectory and the second wellbore trajectory are substantially parallel and separated by a substantially constant distance.

20. The method of claim 19, wherein the first orientation and tilt component includes a seismic source that generates seismic pulses.

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