Patent Publication Number: US-2023151728-A1

Title: Multi-Well Image Reference Magnetic Ranging &amp; Interception

Description:
BACKGROUND 
     Borehole drilled into subterranean formations may enable recovery of desirable fluids (e.g., hydrocarbons) using any number of different techniques. When developing and drilling boreholes, it is important to be able to position the active borehole where desired proximate the surrounding geology of the subterranean formation and proximate adjacent boreholes. As drilling operations progress, the borehole position may change over time relative to adjacent boreholes. 
     During drilling operations, a borehole may become obstructed, which may prevent further drilling operations and/or recovery operations. The obstruction may be so severe an interception operation may be required. The interception operation may require a second drilling operation to intercept the obstructed borehole. Interception operations are difficult in that there may not be metal within the borehole for which a resistivity assembly may be used to identify where the borehole is in a formation. Currently, there is no proven interception method of borehole (i.e., open hole wellbores) that have significant nonconductive obstructions between the desired intercept point and the last set casing shoe. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       These drawings illustrate certain aspects of some examples of the present disclosure and should not be used to limit or define the disclosure. 
         FIG.  1    illustrates an example of an interception operation; 
         FIG.  2    is a workflow to determine the location of a target borehole; and 
         FIGS.  3 - 5    illustrate different examples of ranging operations. 
     
    
    
     DETAILED DESCRIPTION 
     As discussed below, systems and methods for operations in which a magnetic ranging operations, alone, may not be able to identify and intercept a borehole. The systems and methods described below may be utilized in a relief well scenario, complex plug and abandonment or high-risk collision avoidance. By utilizing imaging tool and ranging tools from multiple boreholes, an accurate layout of borehole configuration and tool location may be found. 
       FIG.  1    illustrates a drilling system  100 . As illustrated, wellbore  102  may extend from a wellhead  104  into a subterranean formation  106  from a surface  108 . Generally, wellbore  102  may include horizontal, vertical, slanted, curved, and other types of wellbore geometries and orientations. Wellbore  102  may be cased or uncased. In examples, wellbore  102  may include a metallic member. By way of example, the metallic member may be a casing, liner, tubing, or other elongated steel tubular disposed in wellbore  102 . 
     As illustrated, wellbore  102  may extend through subterranean formation  106 . As illustrated in  FIG.  1   , wellbore  102  may extend generally vertically into the subterranean formation  106 , however wellbore  102  may extend at an angle through subterranean formation  106 , such as horizontal and slanted wellbores. For example, although  FIG.  1    illustrates a vertical or low inclination angle well, high inclination angle or horizontal placement of the well and equipment may be possible. It should further be noted that while  FIG.  1    generally depict land-based operations, those skilled in the art may recognize that the principles described herein are equally applicable to subsea operations that employ floating or sea-based platforms and rigs, without departing from the scope of the disclosure. 
     As illustrated, a drilling platform  110  may support a derrick  112  having a traveling block  114  for raising and lowering drill string  116 . Drill string  116  may include, but is not limited to, drill pipe and coiled tubing, as generally known to those skilled in the art. A kelly  118  may support drill string  116  as it may be lowered through a rotary table  120 . A drill bit  122  may be attached to the distal end of drill string  116  and may be driven either by a downhole motor and/or via rotation of drill string  116  from surface  108 . Without limitation, drill bit  122  may include, roller cone bits, PDC bits, natural diamond bits, any hole openers, reamers, coring bits, and the like. As drill bit  122  rotates, it may create and extend wellbore  102  that penetrates various subterranean formations  106 . A pump  124  may circulate drilling fluid through a feed pipe  126  through kelly  118 , downhole through interior of drill string  116 , through orifices in drill bit  122 , back to surface  108  via annulus  128  surrounding drill string  116 , and into a retention pit  132 . 
     With continued reference to  FIG.  1   , drill string  116  may begin at wellhead  104  and may traverse wellbore  102 . Drill bit  122  may be attached to a distal end of drill string  116  and may be driven, for example, either by a downhole motor and/or via rotation of drill string  116  from surface  108 . Drill bit  122  may be a part of bottom hole assembly (BHA)  130  at distal end of drill string  116 . BHA  130  may further include tools for look-ahead resistivity applications. As will be appreciated by those of ordinary skill in the art, BHA  130  may be a measurement-while drilling (MWD) or logging-while-drilling (LWD) system. 
     BHA  130  may comprise any number of tools, transmitters, and/or receivers to perform downhole measurement operations. For example, as illustrated in  FIG.  1   , BHA  130  may include an imaging assembly  134 . It should be noted that imaging assembly  134  may make up at least a part of BHA  130 . Without limitation, any number of different measurement assemblies, communication assemblies, battery assemblies, and/or the like may form BHA  130  with imaging assembly  134 . Additionally, imaging assembly  134  may form BHA  130  itself. In examples, imaging assembly  134  may comprise at least one transmitter  136  and at least one receiver  137 . In some examples, transmitter  136  and receivers  137  may include loop antennae/coils that may be tilted/disposed at an angle (e.g., 45 degrees) relative to a longitudinal axis (e.g., z axis) of imaging assembly  134 . In some examples, receivers  137  may be collocated (e.g., intersecting loops), However, it should be noted that there may be any number of transmitters  136  and receivers  137  disposed along BHA  130  at any degree from each other. Additionally, transmitters  136  and receivers  137  may be aligned on top of each other and spaced about the axis of BHA  130 . 
     Without limitation, BHA  130  and all parts within BHA  130  (i.e., transmitters  136  and receivers  137 ) may be connected to and/or controlled by information handling system  138 , which may be disposed on surface  108 . Without limitation, information handling system  138  may be disposed downhole in BHA  130 . Processing of information recorded may occur downhole and/or on surface  108 . Processing occurring downhole may be transmitted to surface  108  to be recorded, observed, and/or further analyzed. Additionally, information recorded on information handling system  138  that may be disposed downhole may be stored until BHA  130  may be brought to surface  108 . In examples, information handling system  138  may communicate with BHA  130  through a communication line (not illustrated) disposed in (or on) drill string  116 . In examples, wireless communication may be used to transmit information back and forth between information handling system  138  and BHA  130 . Information handling system  138  may transmit information to BHA  130  and may receive as well as process information recorded by BHA  130 . In examples, a downhole information handling system (not illustrated) may include, without limitation, a microprocessor or other suitable circuitry, for estimating, receiving and processing signals from BHA  130 . Downhole information handling system (not illustrated) may further include additional components, such as memory, input/output devices, interfaces, and the like. In examples, while not illustrated, BHA  130  may include one or more additional components, such as analog-to-digital converter, filter and amplifier, among others, which may be used to process the measurements of BHA  130  before they may be transmitted to surface  108 . Alternatively, raw measurements from BHA  130  may be transmitted to surface  108 . 
     Any suitable technique may be used for transmitting signals from BHA  130  to surface  108 , including, but not limited to, wired pipe telemetry, mud-pulse telemetry, acoustic telemetry, and electromagnetic telemetry. While not illustrated, BHA  130  may include a telemetry subassembly that may transmit telemetry data to surface  108 . At surface  108 , pressure transducers (not shown) may convert the pressure signal into electrical signals for a digitizer (not illustrated). The digitizer may supply a digital form of the telemetry signals to information handling system  138  via a communication link  140 , which may be a wired or wireless link. The telemetry data may be analyzed and processed by information handling system  138 . 
     As illustrated, communication link  140  (which may be wired or wireless, for example) may be provided that may transmit data from BHA  130  to an information handling system  138  at surface  108 . Information handling system  138  may include a personal computer  141 , a video display  142 , a keyboard  144  (i.e., other input devices.), and/or non-transitory computer-readable media  146  (e.g., optical disks, magnetic disks) that can store code representative of the methods described herein. In addition to, or in place of processing at surface  108 , processing may occur downhole. 
     As discussed below, methods may be utilized by information handling system  138  to determine properties of subterranean formation  106 . Information may be utilized to produce an image, which may be generated into a two or three-dimensional models of subterranean formation  106 . These models may be used for well planning, (e.g., to design a path of wellbore  102 ). Additionally, they may be used for planning the placement of drilling systems within a prescribed area. This may allow for the most efficient drilling operations to reach a subsurface structure. During drilling operations, measurements taken within wellbore  102  may be used to adjust the geometry of wellbore  102  in real time to reach a geological target. Measurements collected from BHA  130  of the formation properties may be used to steer drilling system  100  toward a subterranean formation  106 . 
       FIG.  1    illustrates a cross-sectional view of a well measurement system  200 . As illustrated, well measurement system  200  may comprise downhole tool  202  attached a vehicle  204 . In examples, it should be noted that downhole tool  202  may not be attached to a vehicle  204 . Downhole tool  202  may be supported by rig  206  at surface  108 . Downhole tool  202  may be tethered to vehicle  204  through conveyance  210 . Conveyance  210  may be disposed around one or more sheave wheels  212  to vehicle  204 . Conveyance  210  may include any suitable means for providing mechanical conveyance for downhole tool  202 , including, but not limited to, wireline, slickline, coiled tubing, pipe, drill pipe, downhole tractor, or the like. In some embodiments, conveyance  210  may provide mechanical suspension, as well as electrical and/or optical connectivity, for downhole tool  202 . Conveyance  210  may comprise, in some instances, a plurality of electrical conductors and/or a plurality of optical conductors extending from vehicle  204 , which may provide power and telemetry. In examples, an optical conductor may utilize a battery and/or a photo conductor to harvest optical power transmitted from surface  108 . Conveyance  210  may comprise an inner core of seven electrical conductors covered by an insulating wrap. An inner and outer steel armor sheath may be wrapped in a helix in opposite directions around the conductors. The electrical and/or optical conductors may be used for communicating power and telemetry between vehicle  204  and downhole tool  202 . Information from downhole tool  202  may be gathered and/or processed by information handling system  138 . For example, signals recorded by receiver  148  may be stored on memory and then processed by downhole tool  202 . 
     The processing may be performed real-time during data acquisition or after recovery of downhole tool  202 . For this disclosure, real-time is a duration of time ranging from about a second to about ten minutes. Processing may alternatively occur downhole or may occur both downhole and at surface. In some embodiments, signals recorded by downhole tool  202  may be conducted to information handling system  138  by way of conveyance  210 . Information handling system  138  may process the signals, and the information contained therein may be displayed for an operator to observe and stored for future processing and reference. Information handling system  138  may also contain an apparatus for supplying control signals and power to downhole tool  202 . 
     Systems and methods of the present disclosure may be implemented, at least in part, with information handling system  138 . While shown at surface  108 , information handling system  138  may also be located at another location, such as remote from wellbore  102 . Information handling system  138  may include any instrumentality or aggregate of instrumentalities operable to compute, estimate, classify, process, transmit, receive, retrieve, originate, switch, store, display, manifest, detect, record, reproduce, handle, or utilize any form of information, intelligence, or data for business, scientific, control, or other purposes. For example, an information handling system  138  may be a personal computer  141 , a network storage device, or any other suitable device and may vary in size, shape, performance, functionality, and price. Information handling system  138  may include random access memory (RAM), one or more processing resources such as a central processing unit (CPU) or hardware or software control logic, ROM, and/or other types of nonvolatile memory. Additional components of the information handling system  138  may include one or more disk drives, one or more network ports for communication with external devices as well as various input and output (I/O) devices, such as a keyboard  144 , a mouse, and a video display  142 . Information handling system  138  may also include one or more buses operable to transmit communications between the various hardware components. Furthermore, video display  142  may provide an image to a user based on activities performed by personal computer  141 . For example, producing images of geological structures created from recorded signals. By way of example, video display unit may produce a plot of depth versus the two cross-axial components of the gravitational field and versus the axial component in borehole coordinates. The same plot may be produced in coordinates fixed to the Earth, such as coordinates directed to the North, East and directly downhole (Vertical) from the point of entry to the borehole. A plot of overall (average) density versus depth in borehole or vertical coordinates may also be provided. A plot of density versus distance and direction from the borehole versus vertical depth may be provided. It should be understood that many other types of plots are possible when the actual position of the measurement point in North, East and Vertical coordinates is taken into account. Additionally, hard copies of the plots may be produced in paper logs for further use. 
     Alternatively, systems and methods of the present disclosure may be implemented, at least in part, with non-transitory computer-readable media  146 . Non-transitory computer-readable media  146  may include any instrumentality or aggregation of instrumentalities that may retain data and/or instructions for a period of time. Non-transitory computer-readable media  146  may include, for example, storage media such as a direct access storage device (e.g., a hard disk drive or floppy disk drive), a sequential access storage device (e.g., a tape disk drive), compact disk, CD-ROM, DVD, RAM, ROM, electrically erasable programmable read-only memory (EEPROM), and/or flash memory; as well as communications media such wires, optical fibers, microwaves, radio waves, and other electromagnetic and/or optical carriers; and/or any combination of the foregoing. 
     In examples, rig  206  includes a load cell (not shown) which may determine the amount of pull on conveyance  210  at the surface of wellbore  102 . Information handling system  138  may comprise a safety valve (not illustrated) which controls the hydraulic pressure that drives drum  226  on vehicle  204  which may reel up and/or release conveyance  210  which may move downhole tool  202  up and/or down wellbore  102 . The safety valve may be adjusted to a pressure such that drum  226  may only impart a small amount of tension to conveyance  210  over and above the tension necessary to retrieve conveyance  210  and/or downhole tool  202  from wellbore  102 . The safety valve is typically set a few hundred pounds above the amount of safe pull on conveyance  210  such that once that limit is exceeded, further pull on conveyance  210  may be prevented. 
     As illustrated in  FIG.  1   , downhole tool  202  may include imaging assembly  134 . It should be noted that imaging assembly  134  may make up at least a part of downhole tool  202 . Without limitation, any number of different measurement assemblies, communication assemblies, battery assemblies, and/or the like may form downhole tool  202  with imaging assembly  134 . Additionally, imaging assembly  134  may form downhole tool  202  itself. In examples, imaging assembly  134  may comprise at least one transmitter  136  and at least one receiver  137 . As noted above, transmitters  136  and receivers  137  may be transducers. Additionally, the transmitters  136  and receivers  137  may operate, function, and be disposed according to the systems and methods described above and/or below. 
     With continued Reference to  FIG.  1   ,  FIG.  1    illustrates an interception operation in which drilling system  100  may operate to in conjunction with well measurement system  200  to identify target borehole  300 . Interception operations may be utilized when an obstruction  302  has entered target borehole  300  below casing shoe  304  of wellbore  224 . As illustrated, a reference borehole  306  may be drilled above obstruction  302 . In examples, if reference borehole  306  may not be formed from wellbore  224 , then reference borehole  306  may be formed using drilling operations discussed above to form wellbore  224 . This may be formed in place of reference borehole  306 . Downhole tool  202  with imaging assembly  134  may be lowered into reference borehole  306  to work in conjunction with BHA  130 , as drilling operations  100  operate to form an intercept borehole  308 . In examples, intercept borehole  308  may be formed, using drilling operations described above, to penetrate target borehole  300  below obstruction  302 . 
       FIG.  2    illustrates workflow  400  that determines the location of target borehole  300 . Workflow  400  may begin with block  402  in which a reference borehole  306  and an intercept borehole  308  may be formed in view of the methods described above. Once reference borehole  306  and intercept borehole  308  have been formed, downhole tool  202  and BHA  130  may perform measurement operations, utilizing individual imaging assemblies  134  disposed on downhole tool  202  and BHA  130 . 
     In block  404 , azimuthal direction imaging operations may be performed. Imaging operations may comprise imaging target borehole  300  from reference borehole  306  and/or intercept borehole  308 . It should be noted that imaging assemblies  134 , disposed on both bottom hole assembly  130  and/or downhole tool  202  (e.g., referring to  FIG.  1   ) may be any suitable imaging tool such as a resistivity tool, sonic tool, and/or the like. Additionally, each imaging assembly  134  may be different than their counterparts on different downhole equipment. Using any azimuthal imaging tool (Resistivity, Sonic, etc.), an image of target borehole  300  may be taken from reference borehole  306 , using downhole tool  202 . Generally, imaging assembly  134  may provide a reliable directional reference for finding wellbores but deriving an accurate relative distance has eluded the industry to date during practical applications. The image formed form imaging operations may be utilized with ranging measurements. At the end of imaging operations, imaging tools disposed on bottom hole assembly  130  and/or downhole tool  202  may be removed. However, both bottom hole assembly  130  and/or downhole tool  202  may further comprise ranging tools. 
     In block  406 , active and/or passive ranging operations may be performed using ranging tools disposed on bottom hole assembly  130  and/or downhole tool  202  (e.g., referring to  FIG.  1   ). In examples, these ranging tools may be disposed downhole after removing imaging tools. In other examples, as noted above, ranging tool and imaging tools may both be disposed on bottom hole assembly  130  and/or downhole tool  202  so that both bottom hole assembly  130  and/or downhole tool  202  may not need to be removed from target borehole  300 , reference borehole  306 , and/or intercept borehole  308 . Ranging operations may comprise ranging between reference borehole  306  and intercept borehole  308  to identify distance and direction between two locations. Ranging operations may be performed by downhole tool  202  and/or bottom hole assembly  130  (e.g., referring to  FIG.  1   ). In examples, downhole tool  202  and/o bottom hole assembly  130  may comprise a ranging tool. As ranging operations are generally electromechanical in nature, ranging may not be performed from reference borehole  306  to target borehole  300  and intercept borehole  308  to target borehole  300 . This is due to the lack of metallic material in target borehole  300  that may be utilized in electromagnetic ranging. Direction may be identified by utilizing an azimuthal measurement tool. From intercept borehole  308  to reference borehole  306 , magnetically ranging (active or passive) may be utilized to identify a distance and direction from intercept borehole  308  to reference borehole  306 . In examples, electromechanical ranging may be replaced with acoustic ranging and/or resistivity ranging. 
     Acoustic ranging, in general, may comprise inserting into a wellbore  102  and/or borehole (such as target borehole  300  and/or reference borehole  306 ) a downhole tool  202  (e.g., referring to  FIG.  1   ) with acoustic transmitters and receivers (not illustrated) and inducing an acoustic wave to travel into the walls of wellbore  102  and/or borehole and surrounding formation  106  (e.g., referring to  FIG.  1   ). Acoustic sensing may provide continuous in situ measurements of parameters related to formation or borehole fluid. Additionally, acoustic sensing may provide information similar to a seismic survey whereby acoustic reflections from within formation  106  may be received and measured for (among other quantities) direction and distance from the tool. In examples, downhole tool  202  may operate on a conveyance and may be configured for acoustic ranging, resistivity ranging, and/or electromagnetic ranging. Acoustic logging tool may include an independent power supply and may store the acquired data on memory or transfer data in near real-time to a surface storage or processing unit. 
     Additionally, downhole tool  202  may be used to emit an acoustic signal that travels into formation  106  to provide data about impedance changes that reflect acoustic waves back to the tool. The transmitters may produce monopole, dipole, quadrupole, and other acoustic excitation modes that radiate into the formation. The receivers record direct as well as formation-reflected acoustic waves during a recording interval. Downhole tool  202  or a separately connected tool records the acoustic tool’s orientation during each acoustic emission and recording. A Formation velocity model may be derived independently or from the acoustic receiver data, the orientation data, and the receiver recordings may be combined and processed to measure (among other quantities) reflector direction and distance. Reflector targets include any targets capable of reflecting acoustic energy back to the tool, including faults, bedding, fractures, vugs, and other boreholes. 
     In block  408 , images from  404  and magnetic ranging measurements from block  406  may be utilized in a Multi Well Image Referenced Magnetic Ranging may be instituted to determine distance and direction between each borehole  300 ,  306 , and  308 . This method may use scale factors derived from the images relative to one another, a triangulated position of target borehole  300  based off of the images, which are all referenced back to the relative position of intercept borehole  308  and reference borehole  306  when the Magnetic Ranging operation was performed. Generally, magnetic ranging may be used to solve the relative distance and direction between intercept borehole  308  and reference borehole(s)  306  (e.g., referring to  FIG.  3   , discussed below). Downhole tools  202 , such as the imaging tools described above, may provide a direction to the target borehole  300  (e.g., referring to  FIG.  3   , discussed below). Using the distance and direction to target borehole  300  provided by downhole tool  202 , such as azimuthal/direction imaging tools described above, a relative distance in the horizontal plane between target borehole  300  and intercept borehole  308  and reference borehole(s)  306  may be solved for. Additionally, Scale factors may be derived by utilizing the calculated relative distances to target borehole  300  from each intercept borehole  308  and reference borehole(s)  306 . 
       FIG.  3    illustrates an example of determining target borehole  300  in space from reference borehole  306  and intercept borehole  308 . As illustrates, distance and direction from intercept borehole  308  and reference borehole  306  is identified by line  600 . Distance and direction for line  600  may be found utilizing active or passive ranging techniques described above utilizing ranging processes. Direction, for line  602 , from reference borehole  306  to target borehole  300  is identified by line  602 . Direction may be measured using an azimuthal imaging tool disposed in reference borehole  306 . Additionally, direction from intercept borehole  308  to target wellbore  300  is identified by line  604 . Direction, for line  604 , from intercept borehole  308  to target borehole  300  may be found utilizing an azimuthal imaging tool disposed within intercept borehole  308 . From intercept borehole  308  to target borehole  300  and reference borehole  306  to target borehole  300 , target borehole  300  may appear to either be closer, further, or of the same distance from two relative positions (i.e., along lines  602 ,  604 ). In 2-dimensional linear form, a distance from intercept borehole  308  to target borehole  300  and points reference borehole  306  to target borehole  300  may be derived utilizing the measured difference in which the azimuthal imaging tool identified target borehole  300  and the known distance from intercept borehole  308  to target borehole  300  which are provided from the magnetic ranging determination. 
       FIG.  4    illustrates another example for finding target borehole  300  from reference borehole  306  and intercept borehole  308 . From points intercept borehole  308  to target wellbore  300  and reference borehole  306  to target borehole  300  the imaged target borehole  300  may appear to either be closer, further or of the same distance from two relative positions. In a 2-dimensional nonlinear form, a distance along line  604  and line  602  may be derived utilizing trigonometry in conjunction with the measured difference in which the azimuthal imaging tool identifies target borehole  300  and the known distance, along line  600 , intercept borehole  300  to reference borehole  306 , which may be provided from the magnetic ranging determination 
       FIG.  5    illustrates another example for finding target borehole  300  from reference borehole  306 , intercept borehole  308 , and a secondary reference borehole  500 . If more than one secondary reference borehole  500  is utilized than at least a part of the secondary reference boreholes  500  would be magnetically ranged to one another along with the intercept borehole  306 . Thus, intercept borehole  308  to reference borehole  306  (i.e., line  600 ), intercept borehole  308  to secondary reference borehole  500  (i.e., line  502 ), and reference borehole  306  to secondary reference borehole  500  (i.e., line  504 ) may have magnetic ranging determination operations performed to providing a distance and direction. This in addition distance along line  604  and line  602 , which are found using the methods and systems described above. This may allow for more complex and precise triangulation calculations to be made in determining the position of the wellbore and a scale factor to be used for the azimuthal imaging tool. 
     In examples, described above, determining location of target borehole  300  may utilizing linear algebraic formulas to produce a “best fit” of the relative position in space that target borehole  300  may be located. The inputs into the liner algebraic formulas may provide for scale factor “calibration” of the azimuthal imaging tool and the magnetic ranging determinations between intercept borehole  308  and reference borehole  306 . 
     The methods and systems discussed above are improvements over current technology. Improvements over current technology may be seen in the operation that combines an azimuthal imaging ability to see the direction of an anomaly different to the formation (whether that be resistance, acoustic etc.), the utilization of triangulation, combined with the accuracy of magnetic ranging to determine a highly accurate relative distance between at least two objects. This process may allow for determining the position of a wellbore that may be unseen by an electromagnetic downhole tool. This may happen during operations in which independent active magnetic ranging systems are unable to create an electromagnetic field on the target well casing due to high resistant formations or casing strings that have significant damage disrupting electrical continuity. Disruption in electrical continuity may impact the ability to generate an electromagnetic field with AC current from the independent active magnetic ranging system. 
     Systems and methods for ranging and imaging may include any of the various features disclosed herein, including one or more of the following statements. 
     Statement 1: A method may comprise disposing a bottom hole assembly into an intercept borehole, wherein the bottom hole assembly (BHA) comprises an imaging tool and a ranging tool, disposing a downhole tool into a reference borehole, wherein the downhole tool comprises a second imaging tool and a second ranging tool, imaging a target borehole with the imaging tool to form a first image, and imaging the target borehole with the second imaging tool to form a second image. The method may further comprise identifying a distance and a direction between the intercept borehole and the reference borehole using the ranging tool and the second ranging tool, and combining the first image, the second image, the distance, and the direction to find a second direction and a second distance to the target borehole from the intercept borehole. 
     Statement 2: The method of statement 1, further comprising applying a scale factor to the second direction and the second distance. 
     Statement 3: The method of statements 1 or 2, further comprising penetrating the target borehole with the intercept borehole using the BHA. 
     Statement 4: The method of any preceding statements 1-3, wherein the imaging tool and the second imaging tool is an acoustic imaging tool. 
     Statement 5: The method of any preceding statements 1-4, wherein the imaging tool and the second imaging tool is a resistivity imaging tool. 
     Statement 6: The method of any preceding statements 1-5, wherein the ranging tool and the second imaging tool are an electromagnetic ranging tool. 
     Statement 7. The method of any preceding statements 1-6, wherein the ranging tool and the second imaging tool are an acoustic ranging tool. 
     Statement 8: The method of any preceding statements 1-7, wherein the ranging tool and the second imaging tool are a resistivity ranging tool. 
     Statement 9: The method of any preceding statements 1-8, wherein the reference borehole is formed from a drilling operation. 
     Statement 10. The method of any preceding statements 1-9, wherein the reference borehole is attached to and formed from the target borehole. 
     Statement 11. A non-transitory computer readable medium having data stored therein representing a software executable by a computer, the software executable including instructions comprising instructions to accept one or more images from an imaging tool or a second imaging tool, instructions to accept one or more ranging measurements form a ranging tool or a second ranging tool, and instructions to identify a distance and a direction between a target borehole and an intercept borehole using the one or more images and the one or more ranging measurements. 
     Statement 12. The non-transitory computer readable medium of statement 11, wherein the instruction further comprises instructions to apply a scale factor the distance and the direction. 
     Statement 13. The non-transitory computer readable medium of statements 11 or 12, wherein the imaging tool and the ranging tool are disposed on a bottom hole assembly (BHA). 
     Statement 14. The non-transitory computer readable medium of any previous statements 11-13, wherein the imaging tool and the ranging tool are disposed on a downhole tool. 
     Statement 15. The non-transitory computer readable medium of any previous statements 11-14, wherein the imaging tool is a resistivity imaging tool. 
     Statement 16. The non-transitory computer readable medium of any previous statements 11-15, wherein the imaging tool is an acoustic imaging tool. 
     Statement 17. The non-transitory computer readable medium of any previous statements 11-16, wherein the ranging tool is an electromagnetic ranging tool. 
     Statement 18. The non-transitory computer readable medium of any previous statements 11-17, wherein the ranging tool is an acoustic ranging tool. 
     Statement 19. The non-transitory computer readable medium of any previous statements 11-18, wherein the ranging tool is a resistivity ranging tool. 
     Statement 20. The non-transitory computer readable medium of any previous statements 11-19, further comprises sending instructions to guide a bottom hole assembly (BHA) in an intercept borehole to penetrate a target borehole based at least in part on the distance and the direction. 
     It should be understood that, although individual examples may be discussed herein, the present disclosure covers all combinations of the disclosed examples, including, without limitation, the different component combinations, method step combinations, and properties of the system. It should be understood that the compositions and methods are described in terms of “comprising,” “containing,” or “including” various components or steps, the compositions and methods can also “consist essentially of” or “consist of” the various components and steps. Moreover, the indefinite articles “a” or “an,” as used in the claims, are defined herein to mean one or more than one of the elements that it introduces. 
     Therefore, the present examples are well adapted to attain the ends and advantages mentioned as well as those that are inherent therein. The particular examples disclosed above are illustrative only, and may be modified and practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein. Although individual examples are discussed, the disclosure covers all combinations of all of the examples. Furthermore, no limitations are intended to the details of construction or design herein shown, other than as described in the claims below. Also, the terms in the claims have their plain, ordinary meaning unless otherwise explicitly and clearly defined by the patentee. It is therefore evident that the particular illustrative examples disclosed above may be altered or modified and all such variations are considered within the scope and spirit of those examples. If there is any conflict in the usages of a word or term in this specification and one or more patent(s) or other documents that may be incorporated herein by reference, the definitions that are consistent with this specification should be adopted.