System and Method for Providing a Continuous Wellbore Survey

BACKGROUND
Field of the Application

The present application relates generally to surveys of wellbores, and more particularly, to systems and methods for using continuous survey measurements between stationary gyrocompassing survey measurements to produce a continuous wellbore survey for wellbores for oil field and gas field exploration and development.

Description of the Related Art

A survey tool configured to be used in a wellbore can comprise at least one gyroscopic sensor configured to provide at least one data signal indicative of the orientation of the survey tool relative to the rotation axis of the Earth. For example, the at least one gyroscopic sensor can comprise a rate gyroscope (e.g., a spinning gyroscope, typically with the spin axis substantially parallel to the wellbore). The rate gyroscope undergoes precession as a consequence of the Earth's rotation. The rate gyroscope is configured to detect the components of this precession and to generate at least one corresponding data signal indicative of the orientation of the rate gyroscope's spin axis relative to the Earth's axis of rotation. By measuring this orientation relative to the Earth's axis of rotation, the rate gyroscope can determine the orientation of the survey tool relative to true north. Such rate gyroscopes can be used in a gyrocompassing mode while the survey tool is relatively stationary. In certain systems, the survey tool (e.g., a measurement-while-drilling or MWD survey tool) can be part of a steerable drilling tool, and can be used in a gyrosteering mode while drilling is progressing.

SUMMARY

Described herein are implementations of various technologies relating to a system and method for providing a continuous wellbore survey. In one implementation, a method may include acquiring stationary survey data using a survey tool disposed at a stationary position within a previously drilled section of a wellbore, where the survey tool is configured to be deployed to the stationary position within the previously drilled section of the wellbore from a moving platform, and where the stationary position is lower than a predetermined depth within the previously drilled section of the wellbore. The method may also include acquiring continuous survey data during an outrun data acquisition using the survey tool, where the survey tool is configured to ascend within the wellbore during the outrun data acquisition. The method may further include transmitting the continuous survey data and the stationary survey data to a computing system, where the computing system is configured to generate a continuous survey of the previously drilled section of the wellbore based on the continuous survey data and the stationary survey data.

In another implementation, a method may include receiving stationary survey data acquired using a survey tool disposed at a stationary position within a previously drilled section of a wellbore, where the survey tool is configured to be deployed to the stationary position within the previously drilled section of the wellbore from a moving platform, and where the stationary position is lower than a predetermined depth within the previously drilled section of the wellbore. The method may also include receiving continuous survey data acquired during an outrun data acquisition using the survey tool, where the survey tool is configured to ascend within the wellbore during the outrun data acquisition. The method may further include generating a continuous survey of the previously drilled section of the wellbore based on the continuous survey data and the stationary survey data.

In yet another implementation, a survey tool may include one or more sensors, where the one or more sensors are configured to acquire stationary survey data while the survey tool is disposed at a stationary position within a previously drilled section of a wellbore. The survey tool may be configured to be deployed to the stationary position within the previously drilled section of the wellbore from a moving platform, where the stationary position is lower than a predetermined depth within the previously drilled section of the wellbore. The one or more sensors may also be configured to acquire continuous survey data during an outrun data acquisition, where the survey tool is configured to ascend within the wellbore during the outrun data acquisition. The survey tool may also include a processor and a memory including a plurality of program instructions which, when executed by the processor, cause the processor to transmit the continuous survey data and the stationary survey data to a computing system, where the computing system is configured to generate a continuous survey of the previously drilled section of the wellbore based on the continuous survey data and the stationary survey data.

The above referenced summary section is provided to introduce a selection of concepts in a simplified form that are further described below in the detailed description section. The summary is not intended to identify key features or essential features of the claimed subject matter, nor is it intended to be used to limit the scope of the claimed subject matter. Furthermore, the claimed subject matter is not limited to implementations that solve any or all disadvantages noted in any part of this disclosure.

BRIEF DESCRIPTION OF THE DRAWINGS

Various configurations are depicted in the accompanying drawings for illustrative purposes, and should in no way be interpreted as limiting the scope of the systems or methods described herein. In addition, various features of different disclosed configurations can be combined with one another to form additional configurations, which are part of this disclosure. Any feature or structure can be removed, altered, or omitted. Throughout the drawings, reference numbers may be reused to indicate correspondence between reference elements.

Implementations of various techniques will hereafter be described with reference to the accompanying drawings. It should be understood, however, that the accompanying drawings illustrate only the various implementations described herein and are not meant to limit the scope of various techniques described herein.

FIG. 1A schematically illustrates an example system in accordance with certain embodiments described herein.

FIG. 1B schematically illustrates another example system in accordance with certain embodiments described herein.

FIG. 2 is a flow diagram of an example method for generating data to be used in producing a continuous wellbore survey of a previously drilled portion of a wellbore in accordance with certain embodiments as described herein.

FIG. 3 is a flow diagram of an example method for producing a continuous wellbore survey of a previously drilled portion of a wellbore in accordance with certain embodiments described herein.

FIGS. 4A-4E schematically illustrate various examples of the stationary survey measurements and the continuous surveys in accordance with certain embodiments described herein.

FIG. 5A schematically illustrates an example process for combining the plurality of stationary survey measurements and the plurality of continuous survey measurements to produce a continuous survey of the previously drilled portion of the wellbore in accordance with certain embodiments described herein.

FIG. 5B schematically illustrates another example process for combining the plurality of stationary survey measurements and the plurality of continuous survey measurements to produce a continuous survey of the previously drilled portion of the wellbore in accordance with certain embodiments described herein.

FIG. 6 schematically illustrates an example process for correcting the continuous survey for bias errors in accordance with certain embodiments described herein.

FIG. 7 illustrates a schematic diagram of a gyrocompassing survey operation in accordance with implementations of various techniques described herein.

FIG. 8 illustrates a flow diagram of a method for generating a continuous or near continuous survey of a wellbore in accordance with implementations of various techniques described herein.

FIG. 9 illustrates a process for combining the continuous survey data and the stationary survey data in accordance with implementations of various techniques described herein.

FIG. 10 illustrates a flow diagram of a method for generating a continuous survey of a wellbore in accordance with implementations of various techniques described herein.

FIG. 11 illustrates a schematic diagram of a survey operation in accordance with implementations of various techniques described herein.

FIG. 12 illustrates a flow diagram of a method for generating a continuous survey of a wellbore from a moving platform using a survey tool in accordance with implementations of various techniques described herein.

FIG. 13 illustrates a block diagram of a hardware configuration in which one or more various technologies described herein may be incorporated and practiced.

DETAILED DESCRIPTION

Although certain configurations and examples are disclosed herein, the subject matter extends beyond the examples in the specifically disclosed configurations to other alternative configurations and/or uses, and to modifications and equivalents thereof. Thus, the scope of the claims appended hereto is not limited by any of the particular configurations described below. For example, in any method or process disclosed herein, the acts or operations of the method or process may be performed in any suitable sequence and are not necessarily limited to any particular disclosed sequence. Various operations may be described as multiple discrete operations in turn, in a manner that may be helpful in understanding certain configurations; however, the order of description should not be construed to imply that these operations are order-dependent. Additionally, the structures, systems, and/or devices described herein may be embodied as integrated components or as separate components. For purposes of comparing various configurations, certain aspects and advantages of these configurations are described. Not necessarily all such aspects or advantages are achieved by any particular configuration. Thus, for example, various configurations may be carried out in a manner that achieves or optimizes one advantage or group of advantages as taught herein without necessarily achieving other aspects or advantages as may also be taught or suggested herein.

In the discussion herein, attention is focused on certain embodiments in which systems and methods are used in conjunction with gyrocompassing survey measurements (e.g., gyroscopic measurements taken while the survey tool is substantially stationary to measure rotations due to the Earth's rotation). The systems and methods described herein may be used in conjunction with survey tools for taking certain types of static/gyrocompassing wellbore surveys, including, but not limited to, wireline survey tools, slick line survey tools (e.g., tools for surveys run on a wireline without communication to the surface), and drop survey tools.

The surveys of the previously drilled portion of the wellbore can be taken by a survey tool either as the survey tool is inserted into (e.g., an inrun survey) or extracted from (e.g., an outrun survey) the portion of the wellbore after the portion of the wellbore has been drilled. In addition, the surveys of the previously drilled portion of the wellbore can be taken during an outrun survey, for example, using sensors that are part of a gyro-while-drilling (GWD) drill string or a measurement-while-drilling (MWD) drill string that is used to drill the wellbore, and the sensors of the GWD or MWD drill string are used to take measurements while the drill string is extracted from the wellbore (as opposed to being used while the drill string is drilling the wellbore and being extended downward along the wellbore) after the portion of the wellbore has been drilled. In certain embodiments, the sensors used to take the plurality of continuous survey measurements are located in a portion of the drill string that rotates as drilling is performed.

As with other downhole measurement systems and methods, in certain embodiments described herein, the situation downhole is not known precisely, and failure of the survey tool to become totally static when measurement data are collected may degrade the accuracy of the survey. However, due to the measurements being taken of a previously drilled portion of the wellbore, the results of the analysis described herein are not available while the portion of the wellbore is being drilled. Instead, the results of the analysis described herein are available after the portion of the wellbore has been drilled but before further activity involving the portion of the wellbore.

For example, it can be desirable to accurately determine the true path or trajectory of a previously drilled wellbore, including portions of the wellbore having significant deviations from the predetermined plan for the wellbore path. Different drilling methods may result in more deviations than others (e.g., paths that have more tortuous trajectories than others), and detailed data regarding the wellbore path or trajectory which takes account of short-term perturbations in the wellbore path can be desirable for a number of reasons, including, but not limited to the identification of low-tortuosity sections for permanent installation of completion or production equipment, and the identification of high-tortuosity sections in which rod guide wear sleeve equipment is to be placed to increase rod and casing life and to reduce workover frequency. Furthermore, detailed knowledge of well tortuosity may help the evaluation of the drilling equipment and process, in particular the steering while drilling performance, and for extended reach drilling. In certain embodiments, the systems and methods described herein advantageously provide a very precise and detailed continuous survey of a previously drilled portion of a wellbore, taking account of “micro-tortuosity” of the wellbore trajectory.

Current gyroscopic survey techniques include stationary and continuous techniques. When taking a gyrocompassing survey measurement within a wellbore, it is desirable that the survey tool remains perfectly stationary with respect to the Earth while the data is collected. Being stationary ensures that the at least one gyroscopic sensor module of the survey tool is subject only to the rotational motion of the Earth while the measurements are being made. Stationary gyroscopic surveys typically have sequential gyrocompassing measurements taken at positions within the wellbore that are spaced from one another by pipe or stand length intervals (e.g., 30-90 feet), with these measurements being used to determine wellbore inclination and azimuth. Positional data can be derived by combining the angular information from the gyrocompassing measurements with measurements of the depth of the survey tool along the wellbore using a curve-fitting process to establish the trajectory of the wellbore. Continuous gyroscopic surveys are typically implemented by measuring the changes in inclination and azimuth at more frequent intervals along the wellbore (e.g., one foot), and the absolute inclination and azimuth values can be derived by summing the incremental changes from a known initial orientation. The initial orientation can be established at a reference down-hole position using at least one gyrocompassing survey, or at a reference surface position using fore sighting methods or other sources of attitude data that can be made available above-ground, including, but not limited to, satellite navigation data.

Continuous gyroscopic surveys, in which individual survey stations are taken at frequent intervals (e.g., successive positions spaced from one another by distances along the wellbore in a range between one foot and five feet), are subject to measurement drifts which can propagate and increase in size over long wellbore sections, giving rise to significant azimuth and positional inaccuracies. One existing method of offsetting the effects of such survey measurement drift is to perform drift corrections based on the comparison of inrun survey measurements (e.g., survey measurements taken while the survey tool is moved downward along the wellbore) and outrun survey measurements (e.g., survey measurements taken while the survey tool is moved upward along the wellbore) taken at common positions in the wellbore. An alternative technique is to conduct gyrocompassing surveys at intervals along the wellbore path and to use the resulting information to initialize successive continuous survey sections over shorter depth intervals. In such techniques, the length intervals between these successive continuous survey sections are in a range from 500 to 600 meters, corresponding to approximately 20 minutes duration for typical wireline run operations.

In certain embodiments described herein, a method is provided which combines frequent static survey measurements (e.g., at intervals of 90 feet) with continuous survey measurements taken between the successive static survey measurements. For example, certain embodiments described herein can be used for battery run operations, in which the survey tool traverses the wellbore on a slick line. However, certain embodiments described herein are applicable for any other wireline survey technique as well.

FIG. 1A schematically illustrates an example system 100 in accordance with certain embodiments described herein. The system 100 comprises a tool string 110 configured to be within a wellbore 112 and comprising at least one survey tool 120 configured to perform survey measurements. The system 100 further comprises at least one processor 130 configured to receive signals from the at least one survey tool 120 and to operate in accordance with certain embodiments described herein.

The at least one survey tool 120 can comprise at least one gyro-while-drilling (GWD) survey tool, at least one measurement-while-drilling (MWD) survey tool, or both. In certain embodiments, as schematically illustrated in FIG. 1 A, the at least one survey tool 120 can comprise one survey tool 120 comprising at least one gyroscopic sensor module 122 and at least one accelerometer module 124. In certain such embodiments, the gyroscopes and accelerometers of the one survey tool 120 can be used to perform a combination of the stationary survey measurements and the continuous survey measurements, as described more fully below.

FIG. 1B schematically illustrates an example system 100 in which the at least one survey tool 120 comprises a first survey tool 120a and a second survey tool 120b in accordance with certain embodiments described herein. In certain such embodiments, one of the first survey tool 120a and the second survey tool 120b can be used to perform the stationary survey measurements (e.g., high performance gyrocompassing measurements). The other one of the first survey tool 120a and the second survey tool 120b can be used to perform the continuous survey measurements (e.g., lower grade measurements), keeping track of inclination and azimuth changes between the stationary survey measurements, as described more fully below. The stability and repeatability of the gyroscopic measurements are examples of parameters that can be used in determining the level of performance of a downhole gyrocompassing survey system. For example, gyrocompassing measurements can be characterized as being high performance when the combination of all gyroscopic measurement errors is less than 0.1 degree per hour. Using sensors that provide lower grade measurements (e.g., with measurement uncertainties in a range of 5-10 degrees per hour), it can become more difficult to achieve the desired level of measurement stability and repeatability for precision surveying. In certain other embodiments, the continuous survey measurements can be performed using a survey tool that has the same or higher accuracy than does the survey tool used to perform the stationary survey measurements.

The at least one survey tool 120 comprises at least one gyroscopic sensor module 122 configured to generate signals indicative of measurements of the rotation rate to which the at least one gyroscopic sensor module 122 is exposed. In the example system 100 of FIG. 1B, the at least one gyroscopic sensor module 122 comprises at least one gyroscopic sensor module 122a (e.g., dedicated to stationary survey measurements) of the first survey tool 120a and at least one gyroscopic sensor module 122b (e.g., dedicated to continuous survey measurements) of the second survey tool 120b.

The at least one gyroscopic sensor module 122 can comprise one or more gyroscopes that are dedicated to stationary survey measurements of the Earth's rotation vector (e.g., gyrocompassing survey measurements). For example, the at least one gyroscopic sensor module 122 can comprise one or more gyroscopes selected from the group consisting of: spinning wheel gyroscopes, optical gyroscopes, and Coriolis vibratory sensors (e.g., MEMS vibratory sensors). Example gyroscopic sensors compatible with embodiments described herein are described more fully in “Survey Accuracy is Improved by a New, Small OD Gyro,” G. W. Uttecht, J. P. deWardt, World Oil, March 1983; U.S. Pat. Nos. 5,657,547, 5,821,414, and 5,806,195. These references are incorporated in their entireties by reference herein. Other examples of gyroscopic sensors are described by U.S. Pat. Nos. 6,347,282, 6,957,580, 7,117,605, 7,225,550, 7,234,539, 7,350,410, and 7,669,656 each of which is incorporated in its entirety by reference herein. The at least one gyroscopic sensor module 122 is advantageously capable of providing measurements of turn rate to the desired accuracy (e.g., in a range from 0.01°/hour to 0.05°/hour). The at least one gyroscopic sensor module 122 is advantageously sufficiently small to be accommodated in a down hole tool (e.g., within the confines of a 1¾-inch pressure case), capable of operating over the expected temperature range (e.g., −20° Celsius (C) to +150° C., or greater), and capable of surviving the down hole vibration and shock environment that may be encountered within the wellbore.

The at least one gyroscopic sensor module 122 can further comprise one or more gyroscopes that are dedicated to continuous measurements of changes in orientation in addition to changes of the Earth's rotation vector. For example, the at least one gyroscopic sensor module 122 can comprise one or more MEMS gyroscopes, or other gyroscopes compatible with measuring angular changes in inclination and azimuth over the relatively short periods of time (e.g., one second) that the at least one survey tool 120 would take to move between successive stationary survey positions (e.g., 90 feet). The performance specifications for these gyroscopes are much less demanding, for example, a rate measurement bias stability in the range of 5-10°/hour is adequate. Gyroscopic sensors configured to provide the continuous survey measurements can be relatively small and inexpensive to install in the at least one survey tool 120. In certain embodiments, the one or more gyroscopes dedicated to continuous survey measurements can be installed alongside the one or more gyroscopes dedicated to stationary survey measurements (e.g., in a single tool 120). In certain other embodiments, the one or more gyroscopes dedicated to continuous survey measurements can be mounted in a second gyroscopic sensor module (e.g., gyroscopic sensor module 122b) that is separate but mechanically coupled (e.g., screwed) to a first gyroscopic sensor module (e.g., gyroscopic sensor module 122a) comprising the one or more gyroscopes dedicated to stationary survey measurements.

The at least one survey tool 120 further comprises at least one accelerometer module 124 configured to generate a second one or more signals indicative of measurements of the Earth's gravitation vector at the at least one accelerometer module 124. For example, the at least one accelerometer module 124 can comprise one or more accelerometers that are configured to measure the Earth's gravitation vector (e.g., a triad of accelerometers that provide signals indicative of three orthogonal components of the Earth's gravitation vector at the position of the at least one accelerometer module 124). In certain embodiments, the at least one accelerometer module 124 comprises one or more cross-axial accelerometers configured to sense two or more components of the Earth's gravitation vector.

In certain embodiments, the at least one accelerometer module 124 comprises two or more single-axis accelerometers, one or more two-axis accelerometers, and/or one or more three-axis accelerometers. Various types of accelerometer sensors are capable of providing a desired level of measurement accuracy and resolution compatible with certain embodiments described herein. Examples include, but are not limited to, quartz flexure accelerometer sensors and MEMS devices. The measurement range may be in excess of ±1 unit of standard gravity (g) (e.g., in a range between ±1.2 g and ±1.5 g). The accelerometer sensors are advantageously sufficiently small to be accommodated in a down hole tool (e.g., within the confines of a 1¾-inch pressure case), capable of operating over the expected temperature range (e.g., −20° C. to +150° C., or greater), and capable of surviving the down hole vibration and shock environment that may be encountered within the wellbore.

The resolution and precision of the at least one accelerometer sensors can depend on the time and the desired angular rate uncertainty. For example, for errors below a maximum error on the toolface rate of 0.05°/hour over 15 seconds, the at least one accelerometer can provide noise levels below 0.14 mG. An analog-to-digital system with a range of ±1.2 G and 16 bits can give a resolution of 0.036 mG/count, which can satisfy the desired noise levels. If the time is increased, the accelerometer uncertainty can be increased as well.

In certain embodiments, the at least one accelerometer module 124 comprises a plurality of accelerometers that is part of either a gyro-while-drilling (GWD) survey tool or a measurement-while-drilling (MWD) survey tool (e.g., for determining the inclination and tool face angles at various positions along the wellbore being surveyed). In certain other embodiments, the at least one accelerometer module 124 comprises different pluralities of accelerometers. For example, the at least one accelerometer module 124 can comprise one or more accelerometers that are dedicated to measurements of the Earth's gravitation vector during times at which the survey tool is used for gyrocompassing and one or more accelerometers that are not used for gyrocompassing.

The at least one processor 130 of the example system 100 of FIGS. 1A and 1B (e.g., one or more micro-processors, a standard personal computer) is configured to receive signals from the at least one gyroscopic sensor module 122 and from the at least one accelerometer sensor module 124 of the at least one survey tool 120. In certain embodiments, the at least one processor 130 is located at or above the Earth's surface (e.g., as schematically illustrated by FIGS. 1A and 1B), or is located within the survey tool 120 within the wellbore. In some embodiments, a portion of the at least one processor 130 is located at or above the Earth's surface, and another portion of the at least one processor 130 is located within the wellbore and is communicatively coupled to the portion at or above the Earth's surface.

The at least one processor 130 can comprise one or more hardware processors in communication with at least one computer-readable memory that stores software modules including instructions that are executable by the one or more hardware processors. The software modules can include one or more software modules configured to receive a first plurality of signals from the at least one gyroscopic module 122 of the survey tool 120, to receive a second plurality of signals from the at least one accelerometer sensor module 124 of the survey tool 120, and to use the first plurality of signals and the second plurality of signals in accordance with certain embodiments described herein. In certain embodiments, a non-transitory computer storage can be provided having stored thereon a computer program that instructs a computer system (e.g., the at least one processor 130) to perform one or more methods compatible with certain embodiments described herein.

In certain embodiments, the at least one processor 130 is part of a controller generally configured to control and/or monitor the operation of the tool string 110 or portions thereof, with the controller comprising hardware, software, or a combination of both hardware and software. For example, in certain embodiments in which the tool string 110 comprises a drill string, the at least one processor 130 can be further configured to determine the current orientation or the trajectory of the drill string within the wellbore 112. The at least one processor 130 can further be configured to communicate with a memory subsystem configured to store appropriate information, such as orientation data, data obtained from one or more sensor modules on the drill string, etc.

In certain embodiments, the at least one processor 130 provides a real-time processing analysis of the signals or data obtained from various sensors of the at least one survey tool 120. In certain such real-time processing embodiments, data obtained from the various sensor modules are analyzed in real-time. In certain embodiments, at least a portion of the data obtained from the various sensor modules is saved in memory for analysis by the at least one processor 130. The at least one processor 130 of certain such embodiments comprises sufficient data processing and data storage capacity to perform the real-time analysis. In certain other embodiments, rather than being performed in real-time, the analysis is performed after the surveys have been taken (e.g., post-processing), and the at least one processor 130 comprises sufficient data processing and data storage capacity to perform such post-processing of the previously-obtained surveys.

Certain embodiments described herein can advantageously determine the shape (e.g., trajectory) of the wellbore between successive stationary surveys using a relatively small and inexpensive continuous gyro system (e.g., MEMS gyros) which can include gyros that are of a significantly lower grade than those utilized to generate a definitive survey in conventional surveying systems and operations. Certain embodiments described herein are applicable for different modes of survey operation. For example, for systems that run on electrical wireline, both gyrocompassing and continuous data sets can be transmitted to the surface and a computer at the surface can combine the data appropriately. For another example, such processes can be carried out downhole and the final survey results can be transmitted to the surface. For slick line and drop tool operations, data can be downloaded at the surface after the tool has been retrieved from the wellbore, and data processing can then be performed at the surface.

FIG. 2 is a flow diagram of an example method 200 for generating data for a continuous survey of a previously drilled portion of a wellbore in accordance with certain embodiments as described herein. In an operational block, 210, the method 200 comprises taking a plurality of stationary survey measurements 212 at a corresponding plurality of locations along the portion of the wellbore. In an operational block 220, the method 200 further comprises taking at least one continuous survey 214 comprising a plurality of continuous survey measurements 216 between a pair of stationary survey measurements 212 of the plurality of stationary survey measurements 212.

In certain embodiments, taking the plurality of stationary survey measurements 212 is performed using at least one survey tool (e.g., the at least one survey tool 120 as described herein), and taking the at least one continuous survey 214 is performed using the at least one survey tool. The at least one survey tool can comprise at least one gyroscopic sensor module (e.g., the at least one gyroscopic sensor module 122 as described herein) and at least one accelerometer sensor module (e.g., the at least one accelerometer sensor module 124 as described herein). For example, the at least one gyroscopic sensor module can comprise at least one gyroscopic sensor module that is configured (e.g., dedicated) to performing stationary survey measurements of the Earth's rotation vector (e.g., gyrocompassing survey measurements) and at least one gyroscopic sensor module configured (e.g., dedicated) to performing continuous survey measurements of the Earth's rotation vector (e.g., one or more MEMS gyroscopes). The at least one accelerometer sensor module can comprise at least one accelerometer sensor module that is configured (e.g., dedicated) to measure the Earth's gravitation vector (e.g., as described herein). In certain embodiments, taking the plurality of stationary survey measurements 212 comprises transmitting data from the plurality of stationary survey measurements 212 to a computer system comprising at least one processor (e.g., the at least one processor 130 as described herein), and taking the at least one continuous survey 214 comprises transmitting data from the plurality of continuous survey measurements 216 to the computer system.

In certain embodiments, the at least one survey tool (e.g., the at least one gyroscopic sensor module 122 and the at least one accelerometer sensor module 124) can be moved throughout the wellbore survey operation (e.g., located at sequential positions in an inrun direction downward along the wellbore, located at sequential positions in an outrun direction upward along the wellbore, or both) for performing the stationary survey measurements and the continuous survey measurements. The resulting inrun datasets, the outrun datasets, or both can be transmitted to the computer system and stored by the computer system. In certain embodiments, one or more of the datasets can be transmitted to the computer system while the at least one survey tool is being moved along the wellbore, while in certain other embodiments, one or more of the datasets can be transmitted to the computer system from the at least one survey tool upon retrieval of the at least one survey tool at the Earth's surface, after which the datasets can be processed to produce the combined survey in accordance with certain embodiments described herein.

FIG. 3 is a flow diagram of an example method 300 for producing a continuous survey of a previously drilled portion of a wellbore in accordance with certain embodiments described herein. In an operational block 310, the method 300 comprises receiving a plurality of stationary survey measurements 212 (e.g., a plurality of gyrocompassing survey measurements) taken at a corresponding plurality of locations along the portion of the wellbore. In an operational block 320, the method 300 further comprises receiving at least one continuous survey 214 comprising a plurality of continuous survey measurements 216 taken between a pair of stationary survey measurements 212 of the plurality of stationary survey measurements 212. In an operational block 330, the method 300 further comprises combining the plurality of stationary survey measurements 212 and the plurality of continuous survey measurements 216 to produce a continuous survey of the portion of the wellbore.

In certain embodiments, receiving the plurality of stationary survey measurements 212 in the operational block 310 comprises taking the plurality of stationary survey measurements 212 (e.g., as in the operational block 210) using the at least one survey tool. In certain embodiments, receiving the at least one continuous survey 214 in the operational block 320 comprises taking the at least one continuous survey 214 (e.g., as in the operational block 220) using the at least one survey tool. In certain embodiments, combining the plurality of stationary survey measurements 212 and the plurality of continuous survey measurements 216 in the operational block 330 comprises using a computer system comprising at least one processor (e.g., the at least one processor 130 described herein), the computer system having received the plurality of stationary survey measurements 212 taken by and transmitted from the at least one survey tool and the plurality of continuous survey measurements 216 taken by and transmitted from the at least one survey tool.

In certain embodiments, the at least one continuous survey 214 comprises continuous survey measurements 216 taken between a pair of sequential stationary survey measurements 212 spaced from one another by a distance along the wellbore in a range of 30 feet to 270 feet (e.g., 90 feet, 180 feet, a length corresponding to one pipe length of the wellbore, a length corresponding to two pipe lengths of the wellbore, a length corresponding to three pipe lengths of the wellbore).

FIGS. 4A-4E schematically illustrate various examples of the stationary survey measurements 212 and the continuous surveys 214 in accordance with certain embodiments described herein. In certain embodiments, the at least one continuous survey 214 comprising continuous survey measurements 216 taken between the pair of stationary survey measurements 212 spans across (e.g., includes) the location of at least one stationary survey measurement 212 (e.g., there are one or more stationary survey measurements 212 between the pair of stationary survey measurements 212). For example, as schematically shown in FIG. 4A, the continuous survey 214a comprising continuous survey measurements 216 taken between the pair of stationary survey measurements 212a, 212c spans across (e.g., includes) the location of the stationary survey measurement 212b. In certain other embodiments, the at least one continuous survey 214 spans across (e.g., includes) the location of two or more stationary survey measurements 212.

For another example, as schematically shown in FIG. 4B, the continuous survey 214a comprising continuous survey measurements 216 taken between the pair of stationary survey measurements 212a, 212b spans across (e.g., includes) the locations of the stationary survey measurements 212a, 212b, and the continuous survey 214b comprising continuous survey measurements 216 taken between the pair of stationary survey measurements 212a, 212c spans across (e.g., includes) the locations of the stationary survey measurements 212b, 212c. In other words, the continuous survey 214 can include the locations of the pair of stationary survey measurements 212 that at least a portion of the continuous survey 214 is between.

For still another example, as schematically shown in FIG. 4C, the continuous survey 214a comprising continuous survey measurements 216 taken between the pair of stationary survey measurements 212a, 212b spans across (e.g., includes) the location of the stationary survey measurement 212b, the continuous survey 214b comprising continuous survey measurements 216 taken between the pair of stationary survey measurements 212b, 212c spans across (e.g., includes) the location of the stationary survey measurement 212c, and the continuous survey 214a and the continuous survey 214b at least partially overlap one another. At least some of the continuous survey measurements 216 of the continuous survey 214a can also be continuous survey measurements 216 of the continuous survey 214b (e.g., some continuous survey measurements 216 can be included in two or more continuous surveys 214).

In certain embodiments, the at least one continuous survey 214 comprising continuous survey measurements 216 taken between the pair of stationary survey measurements 212 spans across (e.g., includes) the locations of none of the stationary survey measurements 212 of the plurality of stationary survey measurements 212 (e.g., there are no stationary survey measurements 212 between the pair of stationary survey measurements 212 at either end of the continuous survey 214). For example, as schematically shown in FIG. 4D, the continuous survey 214a comprising continuous survey measurements 216 taken between the pair of stationary survey measurements 212a, 212b does not span across (e.g., include) a location of a stationary survey measurement 212, and the continuous survey 214b comprising continuous survey measurements 216 taken between the pair of stationary survey measurements 212b, 212c does not span across (e.g., include) a location of a stationary survey measurement 212.

In certain embodiments, various combinations of continuous surveys 214 may be taken. For example, as schematically illustrated in FIG. 4E, the continuous survey 214a is between the pair of stationary survey measurements 212a, 212b without spanning across the locations of other stationary survey measurements 212, the continuous survey 214b is between the pair of stationary survey measurements 212a, 212c and spans across (e.g., includes) the location of the stationary survey measurement 212b, and the continuous survey 214c is between the pair of stationary survey measurements 212b, 212c without spanning across the locations of other stationary survey measurements 212. Other combinations of continuous surveys 214 may also be taken in accordance with certain embodiments described herein.

FIGS. 5A and 5B schematically illustrate example processes for combining the plurality of stationary survey measurements 212 and the plurality of continuous survey measurements 216 to produce a continuous survey of the previously drilled portion of the wellbore in accordance with certain embodiments described herein. FIGS. 5A and 5B schematically show a plot of azimuth/inclination versus depth along the wellbore for survey measurements taken during an inrun survey. A pair of stationary survey measurements 212a, 212b (e.g., gyrocompassing survey measurements of azimuth and inclination taken at two different depths along the wellbore) are shown as squares, and a continuous survey 214 comprising a plurality of continuous survey measurements 216 between the stationary survey measurements 212a, 212b is shown as a solid line. The continuous survey 214 spans across (e.g., includes) the location of the stationary survey measurement 212b. A curve fitted to the two stationary survey measurements 212a, 212b by a minimum curvature method is shown by solid line 510, and a combined survey produced by combining the two stationary survey measurements 212a, 212b and the continuous survey measurements 216 of the continuous survey 214 is shown by solid line 512. As can be seen in FIGS. 5A and 5B, the combined survey 512 provides information regarding the tortuosity of the wellbore between the two stationary survey measurements 212a, 212b, while the curve 510 fitted to the two stationary survey measurements 212 contains no such information.

In certain embodiments, the pair of stationary survey measurements 212a, 212b can be used as the start point, the end point, or both for the range of continuous survey measurements 216 to be combined with the stationary survey measurements 212. This process can include adjusting the continuous survey measurements 216, which can comprise reducing (e.g., eliminating) a difference between at least one of the stationary survey measurements 212 of the pair of stationary survey measurements 212 and the continuous survey measurements 216 at the depth of the at least one of the stationary survey measurements 212. Each stationary survey measurement 212 can be used as the start point for the next continuous survey 214, and each segment of the continuous survey 216 can be appropriately adjusted and inserted between the corresponding pair of stationary survey measurements 212 to provide a combined survey. In certain such embodiments, the continuous survey measurements 216 can be adjusted by applying an offset to the continuous survey measurements 216 at depths at or between the stationary survey measurement 212a and the stationary survey measurement 212b. In this way, the continuous survey measurement 216a (e.g., the start point of the continuous survey 214) taken at the depth of the stationary survey measurements 212a can be aligned with the stationary survey measurement 212a. In certain embodiments, rather than having at least some of the adjusted continuous survey measurements 216 be at the same depth as the stationary survey measurements 212, adjusting the continuous survey measurements 216 can comprise reducing (e.g., eliminating) a difference between at least one of the stationary survey measurements 212 of the pair of stationary survey measurements 212 and the continuous survey measurements 216 at a depth within a predetermined distance (e.g., within one foot, within five feet, within ten feet, within 10% of a length of a pipe of the wellbore) from the depth of the at least one of the stationary survey measurements 212.

The continuous survey data can be adjusted accordingly, in one or both of the inclination and azimuth readings. For example, as schematically illustrated in FIG. 5A, the start point 216a of the continuous survey data can be offset (e.g., shifted up or down by applying an offset) by a first amount (α₁) such that the start point 216a of the continuous survey data is coincident with one stationary survey measurement 212a. The end point 216b of the continuous survey data can be offset (e.g., shifted up or down by applying an offset) by a second amount (α₁+α₂) such that the end point 216b is coincident with the other stationary survey measurement 212b. The individual measurements of the continuous survey data between the start point 216a and the end point 216b can then each be offset (e.g., shifted up or down by applying an offset) by a third amount calculated from an interpolation of the first amount and the second amount that is proportional to the distance of the depth of the individual measurement to the depths of the start point 216a and the end point 216b. For another example, the continuous survey data can be rigidly shifted up or down by a first amount such that the start point 216a is coincident with the one stationary survey measurement 212a, and the remaining measurements of the continuous survey data can then be rigidly rotated about the one stationary survey measurement 212a (e.g., rotated about the start point 216a in FIG. 5A such that the continuous survey data maintains its shape) until the end point 216b of the continuous survey data coincides with or is within a predetermined amount from the other stationary survey measurement 212b.

In certain embodiments, the stationary survey measurements 212 and the continuous survey measurements 216 collected over each wellbore section between successive stationary survey depths may be combined together by first computing a weighted average 218a of the start points 212a, 216a and a weighted average 218b of the end points 212b, 216b for the stationary survey measurements 212 and the continuous survey measurements 216 (e.g., for both inclination and azimuth). The weighting factors used can be based on representative error models for the two survey tools used to make these measurements. In configurations in which the stationary survey data is collected using a significantly higher performance gyro system than that used for collecting the continuous survey data, the weighted averages 218a, 218b of the start and end points can coincide closely with the start and end points 212a, 212b of the stationary survey measurements 212.

Once new start and end points 218a, 218b are defined for the wellbore section under consideration, the continuous survey data can be adjusted accordingly, in one or both of the inclination and azimuth readings. For example, as schematically illustrated in FIG. 5B, the start point 216a of the continuous survey data can be offset (e.g., shifted up or down by applying an offset) by a first amount (β₁) such that the start point 216a of the continuous survey data is coincident with the weighted average start point 218a. The end point 216b of the continuous survey data can be offset (e.g., shifted up or down by applying an offset) by a second amount (β₁+β₂) such that the end point 216b is coincident with the weighted average end point 218b. The individual measurements of the continuous survey data between the start point 216a and the end point 216b can then be offset (e.g., shifted up or down by applying an offset) by a third amount calculated from an interpolation of the first amount and the second amount that is proportional to the distance of the depth of the individual measurement to the depths of the start point 216a and the end point 216b. For another example, the continuous survey data can be rigidly shifted up or down by a first amount such that the start point 216a is coincident with the weighted average start point 218a, and the remaining measurements of the continuous survey data can then be rigidly rotated about the weighted average start point 218a (e.g., rotated about the weighted average start point 218a in FIG. 5B such that the continuous survey data maintains its shape) until the end point 216b of the continuous survey data coincides with or is within a predetermined amount from the weighted average end point 218b.

In certain embodiments, the at least one gyroscopic sensor module 122b dedicated to continuous survey measurements can include lower-grade gyroscopic sensors that are significantly susceptible to bias errors (e.g., errors in azimuth, inclination, or both). At locations in which the at least one survey tool 120 has stopped to conduct one or more stationary survey measurements 212 (e.g., at the location of stationary survey measurement 212a of FIGS. 5A and 5B), a comparison can be made (e.g., by the at least one processor 130 of the computer system) between the angular rates measured by the at least one gyroscopic sensor module 122a dedicated to stationary survey measurements and the at least one gyroscopic sensor module 122b dedicated to continuous survey measurements. Differences between the respective x-, y-, and z-axis measurements of these gyroscopic sensor modules 122a, 122b can be assumed to arise as a result of bias errors in the lower-grade sensors of the at least one gyroscopic sensor module 122b dedicated to continuous survey measurements. Based on this assumption; the measurement differences can be interpreted as errors in the lower-grade sensors and corrections can be applied accordingly (e.g., by applying an offset to the continuous survey 214, as shown in FIGS. 5A and 5B).

In certain embodiments, the process of correcting the continuous survey 214 can be extended to account for changes in the bias errors of the lower-grade sensors of the at least one gyroscopic sensor module 122b dedicated to continuous survey measurements. FIG. 6 schematically illustrates an example process for correcting the continuous survey 214 for bias errors in accordance with certain embodiments described herein. For example, the bias error can be assumed to have changed between a starting point of a continuous survey 214 and an ending point of the continuous survey 214 by a predetermined relationship (e.g., a linear change). The continuous survey measurements 216 taken at adjacent survey stations (e.g., adjacent locations of the stationary survey measurements 212 which can be considered to be the location of survey station k and the location of survey station k+1) can be compared to these stationary survey measurements 212 to determine the bias errors (e.g., bias errors in azimuth, inclination, or both) of the continuous survey measurements 216 at these adjacent survey station locations (e.g., bias errors bias_kand bias_k+1). The bias errors for the continuous survey measurements 216 at the locations between these two survey station locations can be assumed to have changed by a predetermined relationship (e.g., linear). The interpolated bias errors can be calculated using this predetermined relationship at locations between the pair of stationary survey measurements 212 (e.g., between the locations of survey station k and survey station k+1). The bias errors for the continuous survey measurements 216 at the locations between the two survey station locations can be corrected by applying offsets to correct for the interpolated bias errors. Such corrections can be made for each continuous survey 214 taken along the wellbore.

In certain embodiments, additional adjustments can be made to the continuous survey 214 to combine it with the pair of stationary survey measurements 212 in a self-consistent manner.

Gyrocompassing Surveys Using Drop Survey Tool

As also noted above, gyrocompassing (i.e., stationary) surveys and continuous surveys may be used to determine the true path or trajectory of a wellbore. In various implementations further described below, a drop survey tool disposed in a previously drilled wellbore may be used to acquire continuous survey data during an inrun data acquisition and to acquire gyrocompassing (i.e., stationary) survey data during an outrun data acquisition. The inrun data acquisition may also be referred to as an inrun data acquisition phase. Likewise, the outrun data acquisition may also be referred to as an outrun data acquisition phase. In particular, as further described below, the drop survey tool may record the continuous survey data as it descends within a drill string, and the drop survey tool may record the gyrocompassing (i.e., stationary) data as the drill string is retrieved from the wellbore. The continuous survey data and the gyrocompassing (i.e., stationary) survey data may be combined and used to generate a continuous survey of the wellbore, which may be used to determine the true path or trajectory of the wellbore.

System

FIG. 7 illustrates a schematic diagram of a gyrocompassing survey operation 700 in accordance with implementations of various techniques described herein. As shown, the gyrocompassing survey operation may be performed using a drop survey tool 720 and a computing system 730.

The drop survey tool 720 may be similar to the survey tool discussed above. The drop survey tool 720 may be disposed within a wellbore 712, and may be used in conjunction with various applications, as discussed below. The drop survey tool 720 may also include one or more gyroscopic sensors 722 and one or more accelerometers 724. As is known in the art, the drop survey tool 720 may be uncoupled from the surface, and may be powered using one or more batteries. Any drop survey tool 720 known to those skilled in the art and configured to carry out the implementations described below may be used.

The drop survey tool 720 may be configured to perform both inrun and outrun data acquisitions, as further described below. In particular, the drop survey tool 720 may acquire continuous survey data during the inrun data acquisition, and may acquire gyrocompassing (i.e., stationary) survey data during the outrun data acquisition.

During the inrun data acquisition, the drop survey tool 720 may be dropped into a drill string (not pictured) of the wellbore 712, record the continuous survey data as it falls within the drill string, and store that data in an electronic memory device (not pictured) in the survey tool 720. The drop survey tool 720 may be configured to land at the bottom of the drill string, such as in an area proximate to a bottom hole assembly of the drill string. In one implementation, the drop survey tool 720 may include a spring mounted to the bottom of the tool and/or any other implementation known in the art that may be used to minimize levels of shock and vibration for the tool 720 as it travels down the wellbore and lands within the drill string.

The continuous survey data recorded as the drop survey tool 720 falls in the drill string may correspond to continuous survey measurements acquired using the one or more gyroscopic sensors 722, the one or more accelerometers 724, and/or any other sensors of the survey tool 720. In particular, the continuous survey data may include measured changes in inclination and azimuth at frequent intervals along the wellbore as the tool 720 falls within the drill string. In one implementation, such intervals may be no greater than every 1 foot along the wellbore. The data sampling frequency of the survey tool 720 may depend on the rate of descent of the tool 720 within the drill string. The faster that the tool 720 moves within the drill string, the higher that the data sampling frequency should be to take account of the trajectory of the wellbore. For example, if, as mentioned above, the tool 720 is to measure changes in inclination and azimuth for every one foot in the wellbore, then the survey tool 720 descending at 200 feet per minute will need a data sampling frequency that is greater than three samples per second.

In some implementations, the drop survey tool 720 may freefall in the drill string after it is initially dropped. However, various implementations for the drop survey tool 720 may be used in order to control a rate of descent within the drill string, and to minimize levels of shock and vibration for the tool 720 as it travels down the wellbore and lands within the drill string, including any implementation known to those skilled in the art. In another implementation, the drop survey tool 720 may include various mechanical components that may engage with the inner diameter of the drill string, thus slowing the rate of descent of the drop survey tool 720.

In addition, the rate of descent of the drop survey tool 720 may be controlled based on the drilling fluid being pumped in the wellbore. In particular, the drill string may be filled with the drilling fluid, where the fluid may be resistant to the free falling of the drop survey tool 720. As such, the rate at which the drilling fluid is pumped in the wellbore may be used to control the speed of the tool 720. In addition, the rate at which the drilling fluid is pumped in the wellbore may be used to control the speed of the tool 720 for any high-angle sections of the wellbore 712. In one implementation, the rate of descent of the tool 720 may be limited to as low as 1-2 feet per minute. In another implementation, the viscosity of the drilling fluid may be changed to alter the rate of descent of the tool 720.

In addition, the continuous survey data also includes depth data acquired by the drop survey tool 720 during the inrun data acquisition. For example, in one implementation, the drop survey tool 720 may include a casing collar locator (not shown). As is known in the art, a casing collar locator may be used to find or locate collars or casing joint ends of the segments that form the casing of the wellbore 712. Given that casing joints may have known spacing, the depth of the survey tool 720 within the wellbore can be determined if the casing collars or joints can be correctly counted. As such, the casing collar locator can be used to estimate the depth of the survey tool 720 (i.e., the depth data) at the survey points for the continuous survey data recorded during the inrun data acquisition. In one implementation, the casing collar locator may include one or more magnetic sensors.

In another implementation, the depth of the survey tool 720 (i.e., the depth data) at the survey points for the continuous survey data recorded during the inrun data acquisition can also be determined using the one or more accelerometers 724. In particular, the one or more accelerometers 724 may include a z-axis accelerometer configured to provide measurements of the acceleration along a longitudinal axis (i.e., z-axis) of the survey tool. As such, the z-axis accelerometer may be used to determine the depth of the survey tool 720 at the survey points for the continuous survey data recorded during the inrun data acquisition, particularly if the rate of descent for the tool 720 is substantially constant. In particular, the measurements acquired using the z-axis accelerometer may be integrated twice in order to determine the depth of the survey tool 720 at the survey points. In a further implementation, the depth of the survey tool 720 (i.e., the depth data) at the survey points for the continuous survey data can be determined using both a casing collar locator and the z-axis accelerometer. In particular, the casing collar locator may be used to estimate the depth of collars or casing joint ends of the segments that form the casing of the wellbore 712, while the z-axis accelerometer may be used to determine the depth of the survey tool 720 at points between the joint ends. In yet another implementation, empirical velocity profiles may also be used to determine the depth of the survey tool 720 at the survey points for the continuous survey data recorded during the inrun data acquisition.

As noted above, the drop survey tool 720 may acquire gyrocompassing (i.e., stationary) survey data during the outrun data acquisition. The drop survey tool 720 may perform the outrun data acquisition as the tool 720 is extracted from the wellbore 712. In particular, after being dropped in the drill string and performing the inrun data acquisition, the drop survey tool 720 may land at the bottom of the drill string, such as in an area proximate to a bottom hole assembly of the drill string.

After a period of time, the drill string may be retrieved, such as for the inspection or replacement of a drill bit coupled to the bottom of the drill string. In particular, as is known in the art, the drill string may be composed of multiple sections threadably coupled together. As such, during retrieval, one section of the drill string is pulled out of the wellbore (i.e., recovered), and movement of the drill string is momentarily stabilized. The recovered section of the drill string is then unthreaded from the drill string, and the same retrieval process is repeated for subsequent sections of the drill string. Thus, during the retrieval of the drill string, the drop survey tool 720 positioned at the bottom of the drill string is slowly raised within the wellbore and placed in multiple stationary positions of different depths with respect to the Earth (i.e., each time a section of the drill pipe is unthreaded).

Accordingly, the drop survey tool 720 may be configured to acquire stationary survey data as the drill string is being retrieved from the wellbore, during which the tool 720 records the stationary survey data at the multiple stationary positions within the wellbore and stores that data in the electronic memory device in the survey tool 720. In particular, the data recorded by the tool 720 at the multiple stationary positions may correspond to stationary survey measurements acquired using the one or more gyroscopic sensors 722, the one or more accelerometers 724, and/or any other sensors of the survey tool 720.

In addition, the stationary survey data also includes depth data acquired by the drop survey tool 720 during the outrun data acquisition. In one implementation, the depth of the survey tool 720 (i.e., the depth data) at the survey points for the stationary survey data recorded during the outrun data acquisition can be determined based on the known lengths of the drill string and of each section of the drill string that is pulled out during the retrieval process. For example, if each section of the drill string is 90 feet long, then the tool 720 may record data at multiple positions along the wellbore 712 that are spaced at 90 feet from each other. In another implementation, systems known to those skilled in the art may be used to track the depth of a drill bit coupled to the drill string. As such, the depth of the survey tool 720 at the survey points can be determined based on the known depths of the drill bit, such as by applying an offset to the known depths of the drill bit during the gyrocompassing survey.

In a further implementation, the drop survey tool 720 may include a computing system (not shown), which may switch the drop survey tool 720 between a continuous survey mode, during which the continuous survey data can be acquired, and a stationary survey mode (or gyrocompassing survey mode), during which the stationary survey data can be acquired. In one such implementation, the tool 720 may switch from the continuous survey mode to the stationary survey mode after a predetermined period of time. In particular, the tool 720 may initially be set to the continuous survey mode, which allows for the acquisition of continuous survey measurements using the one or more gyroscopic sensors 722, the one or more accelerometers 724, and/or any other sensors of the survey tool 720. After the predetermined period of time from the start of the inrun data acquisition, during which the tool 720 is dropped and records the continuous survey data corresponding to the continuous survey measurements, the tool 720 may be switched to the stationary survey mode. After being set to the stationary survey mode, the tool 720 may be configured to acquire stationary survey measurements using the one or more gyroscopic sensors 722, the one or more accelerometers 724, and/or any other sensors of the survey tool 720.

In another such implementation, the tool 720 may automatically switch from the continuous survey mode to the stationary survey mode based on the motion detected by the one or more gyroscopic sensors 722 and the one or more accelerometers 724. As explained above, the tool 720 comes to a rest in an area proximate to a bottom hole assembly of the drill string after the inrun data acquisition. When the tool 720 comes to a rest, the measurements from the one or more gyroscopic sensors 722 and the one or more accelerometers 724 may stabilize, measuring only components of the Earth's rotation rate and the local gravity vector, respectively. As such, the computing system of the tool 720 may compare the standard deviations of the measurements, monitored over a fixed period of time, against predefined tolerance levels in order to determine when the tool 720 has come to a rest in the area proximate to the bottom hole assembly of the drill string. If the computing system determines that the tool has come to a rest, then the tool 720 may switch to the stationary survey mode.

The one or more gyroscopic sensors 722 of the tool 720 can be any gyroscopic sensor known to those skilled in the art, including those described above with respect to the gyroscopic sensor modules of FIGS. 1A and 1B. In one implementation, as is known to those skilled in the art, the one or more gyroscopic sensors 722 may include three single-axis gyroscopic sensors or two dual-axis gyroscopic sensors, and may be used to provide measurements of the Earth's rotation rate with respect to the x, y, and z axes of the survey tool 720.

In some implementations, the same gyroscopic sensors 722 may be used for acquiring either the continuous survey data or the stationary survey data. In other implementations, different gyroscopic sensors 722 may be dedicated to acquiring either the continuous survey data or the stationary survey data.

The one or more accelerometers 724 may include three single-axis accelerometers configured to provide measurements of the orthogonal components (g_x, g_y, g_z) of the Earth's gravitation vector with respect to the x, y, and z axes of the survey tool 720. Various types of accelerometers may be used, including those described above with respect to the accelerator modules of FIGS. 1A and 1B.

The drop survey tool 720 may also include any other sensors and/or instrumentation known to those skilled in the art, such as the magnetic sensors used with respect to the casing collar locator described above.

The computing system 730 may be used to process the data recorded by the survey tool 720 during both the inrun and the outrun data acquisitions, as further described in a later section. In particular, based on the recorded data, the computing system 730 may be used to generate a continuous survey of the wellbore.

In one implementation, the computing system 730 may be located at the surface, and may be configured to receive or download the recorded data from the tool 720 after the tool 720 has been retrieved from the wellbore 712. The computing system 730 can be any computing system implementation known to those skilled in the art, including the processors described above with respect to FIGS. 1A and 1B. Various implementations of the computing system 730 are also discussed further below in another section.

Method

FIG. 8 illustrates a flow diagram of a method 800 for generating a continuous survey of a wellbore in accordance with implementations of various techniques described herein. In one implementation, method 800 may be at least partially performed by a computing system, such as the computing system 730 discussed above. It should be understood that while method 800 indicates a particular order of execution of operations, in some implementations, certain portions of the operations might be executed in a different order. Further, in some implementations, additional operations or steps may be added to the method 300. Likewise, some operations or steps may be omitted.

At block 810, the computing system may receive continuous survey data acquired during an inrun data acquisition using a drop survey tool, where the drop survey tool is configured to acquire the continuous survey data as the tool descends within a wellbore during the inrun data acquisition. In particular, the continuous survey data may be data corresponding to a plurality of continuous survey measurements acquired during the inrun data acquisition.

As noted above, the drop survey tool may be dropped into a drill string of the wellbore, record data as it falls within the drill string, and store that data in an electronic memory device in the survey tool. Additionally, various implementations for the drop survey tool may be used in order to control a rate of descent within the drill string, and to minimize levels of shock and vibration for the tool as it travels and lands within the drill string. Further, as explained above, the rate of descent of the drop survey tool may be controlled based on the drilling fluid being pumped in the wellbore.

As also noted above, the continuous survey data may include measured changes in inclination and azimuth at frequent intervals along the wellbore as the tool falls within the drill string. In one implementation, such intervals may be no greater than every 1 foot along the wellbore.

The continuous survey data may be acquired using one or more gyroscopic sensors, one or more accelerometers, and/or any other sensors of the survey tool. The continuous survey data can also include depth data acquired during the inrun data acquisition, where the depth data corresponds to the depth of the survey tool at the survey points for the continuous survey data. The depth data can be determined using a casing collar locator, a z-axis accelerometer, and/or the like.

At block 820, the computing system may receive stationary survey data acquired during an outrun data acquisition using the drop survey tool, where the drop survey tool is configured to acquire the stationary survey data as the tool ascends within the wellbore during the outrun data acquisition. In particular, the stationary survey data may be data corresponding to a plurality of stationary survey measurements acquired during the outrun data acquisition.

As noted above, the drop survey tool may be configured to perform the outrun data acquisition as the drill string is being retrieved from the wellbore, during which the tool records stationary survey data at multiple stationary positions within the wellbore and stores that data in the electronic memory device in the survey tool.

The stationary survey data may be acquired using one or more gyroscopic sensors, one or more accelerometers, and/or any other sensors of the survey tool. The stationary survey data can also include depth data acquired during the outrun data acquisition, where the depth data corresponds to depth of the survey tool at the survey points for the stationary survey data. The depth data can be determined based on the known lengths of the drill string and of each section of the drill string that is pulled out during the retrieval process.

At block 830, the computing system may combine the continuous survey data and the stationary survey data. Various methods known to those skilled in the art may be used for combining the continuous survey data and the stationary survey data. In one implementation, the continuous survey data and the stationary survey data may be combined in similar manner as described above with respect to FIGS. 5A and 5B.

FIG. 9 illustrates a process for combining the continuous survey data and the stationary survey data in accordance with implementations of various techniques described herein. In particular, FIG. 9 illustrates a plot of azimuth/inclination versus depth along the wellbore for continuous survey measurement data acquired during an inrun data acquisition and for stationary survey measurement data acquired during an outrun data acquisition.

A pair of stationary survey measurements 912a, 912b acquired during an outrun data acquisition (e.g., gyrocompassing survey measurements of azimuth and inclination taken at two different depths along the wellbore) are shown as squares. In addition, a plurality of continuous survey measurements 916 acquired during an inrun data acquisition at depths between the stationary survey measurements 912a, 912b is shown as a solid line.

In some implementations, the pair of stationary survey measurements 912a, 912b can be used as the start point, the end point, or both for the range of continuous survey measurements 916 to be combined with the stationary survey measurements 912. This process can include adjusting the continuous survey measurements 916, which can comprise reducing (e.g., eliminating) a difference between at least one of the stationary survey measurements 912 and the continuous survey measurements 916 at the depth of the at least one of the stationary survey measurements 912. Each stationary survey measurement 912 can be used as the start point for the next continuous survey measurement 916, and each segment of the continuous survey measurements 916 can be appropriately adjusted and inserted between the corresponding pair of stationary survey measurements 912 to provide a combined survey.

In some implementations, the continuous survey measurements 916 can be adjusted by applying an offset to the continuous survey measurements 916 at depths at or between the stationary survey measurement 912a and the stationary survey measurement 912b. In particular, the continuous survey measurement 916a (e.g., the start point of the continuous survey measurement 916) taken at the same depth of the stationary survey measurements 912a can be aligned with the stationary survey measurement 912a.

In one implementation, rather than having at least some of the adjusted continuous survey measurements 916 be at the same depth as the stationary survey measurements 912, adjusting the continuous survey measurements 916 can comprise reducing (e.g., eliminating) a difference between at least one of the stationary survey measurements 912 of the pair of stationary survey measurements 912 and the continuous survey measurements 916 at a depth within a predetermined distance (e.g., within one foot, within five feet, within ten feet, within 10% of a length of a pipe of the wellbore) from the depth of the at least one of the stationary survey measurements 912. The continuous survey data acquired during the inrun data acquisition can be adjusted accordingly in the inclination and azimuth readings. For example, as schematically illustrated in FIG. 9, the start point 916a of the continuous survey data acquired during the inrun data acquisition can be offset (e.g., shifted up or down by applying an offset) by a first amount (Δ₁) such that the start point 916a of the continuous survey data is coincident with one stationary survey measurement 912a. The end point 916b of the continuous survey data acquired during the inrun data acquisition can be offset (e.g., shifted up or down by applying an offset) by a second amount (Δ₁+Δ₂) such that the end point 916b is coincident with the other stationary survey measurement 912b.

The individual measurements of the continuous survey data between the start point 916a and the end point 916b can then each be offset (e.g., shifted up or down by applying an offset) by a third amount calculated from an interpolation of the first amount and the second amount, where the third amount is proportional to the distance of the depth of the individual measurement to the depths of the start point 916a and the end point 916b.

For another example, the continuous survey data acquired during the inrun data acquisition can be rigidly shifted up or down by a first amount such that the start point 916a is coincident with the one stationary survey measurement 912a, and the remaining measurements of the continuous survey data can then be rigidly rotated about the one stationary survey measurement 912a (e.g., rotated about the start point 216a in FIG. 9, such that the continuous survey data maintains its shape) until the end point 916b of the continuous survey data coincides with or is within a predetermined amount from the other stationary survey measurement 912b.

The combined continuous survey produced by combining the two stationary survey measurements 912a, 912b and the continuous survey measurements 916 is shown by solid line 920. As can be seen in FIG. 9, the combined continuous survey 920 provides information regarding the trajectory, and thus tortuosity, of the wellbore between the two stationary survey measurements 912a, 912b. The process discussed above can be repeated to combine the remaining continuous survey data and stationary survey data in order to produce a combined continuous survey of the wellbore. In particular, the combined continuous survey of the wellbore may provide information regarding the trajectory of the wellbore for discrete intervals along the wellbore, where the discrete intervals may be determined based on the data sampling frequency of the drop survey tool.

In particular, as noted above, it can be desirable to use a continuous survey of a wellbore to more accurately determine the true path or trajectory of a previously drilled wellbore. An accurate determination of the trajectory of a wellbore can be used in the identification of low-tortuosity sections for permanent installation of completion or production equipment, and the identification of high-tortuosity sections in which rod guide wear sleeve equipment is to be placed to increase rod and casing life and to reduce workover frequency. Furthermore, detailed knowledge of well tortuosity may help the evaluation of the drilling equipment and process, in particular the steering while drilling performance, and for extended reach drilling.

For example, the tortuosity information can be helpful in determining where to place one or more pumps in the wellbore. The placement of a pump in a wellbore section having a relatively high tortuosity can reduce the lifetime of the pump dramatically. If installed in a higher-tortuosity section of the wellbore, the pump may be subject to a bending moment due to the shape of the wellbore restricting the ability of the pump rotor to turn freely (e.g., as a result of excess pressure on the bearings or sliding contact between the rotor and the outer casing of the pump), causing the pump to wear out sooner than had the pump been installed in a lower-tortuosity section of the wellbore.

The implementations described above with respect to FIGS. 1-9 may also be used in conjunction with other methods for analyzing the tortuous sections of a wellbore, such as the implementations described in commonly-assigned U.S. patent application Ser. Nos. 14/612,162 and 14/612,168, both of which are herein incorporated by reference.

In another implementation, drift corrections of the drop survey tool may be performed during the inrun data acquisition as the tool descends within the wellbore. Continuous surveys may be subject to measurement drifts, which can propagate and increase in size over long wellbore sections and lead to inaccuracies in inclination and azimuth. As noted above, the rate at which the drilling fluid is pumped in the wellbore may be used to control the speed of the survey tool. Thus, the rate of the drilling fluid may be set such that the survey tool is relatively stationary at a point during the inrun data acquisition. During this point, bias errors relating to drift can be determined for the one or more gyroscopic sensors and/or the one or more accelerometers of the survey tool.

In sum, implementations relating to generating a continuous survey of a wellbore may be used to more accurately determine the true path or trajectory of a previously drilled wellbore. This may be particularly important for wellbores containing severe high dog-legs and sections of high tortuosity, where failure to capture such details of trajectory can lead to errors in knowledge of well locations. As noted above, an accurate determination of the trajectory of a wellbore can be used in the identification of low-tortuosity sections for permanent installation of completion or production equipment, and the identification of high-tortuosity sections in which rod guide wear sleeve equipment is to be placed to increase rod and casing life and to reduce workover frequency.

Continuous Surveys Using Gyro-while-Drilling Tool

As noted above, to determine the trajectory of a wellbore, as is known in the art, a directional survey may be performed to measure the inclination and azimuth at selected positions along the wellbore. In particular, a survey tool may be used within the wellbore to determine the inclination and azimuth along the wellbore. The survey tool may include sensors configured to generate measurements corresponding to the instrument orientation with respect to one or more reference directions and/or to the Earth's gravity, where the measurements may be used to determine azimuth and inclination along the wellbore.

In various implementations further described below, a survey tool disposed in a previously drilled section of the wellbore may be used to acquire continuous survey data during an outrun data acquisition. In particular, the survey tool may be a gyro-while-drilling (GWD) survey tool disposed in a bottom hole assembly (BHA) of a drill string. As described above, an outrun data acquisition may refer to a data acquisition performed as a survey tool is extracted from at least the previously drilled section of the wellbore. In the implementations further described below, during the outrun data acquisition, the GWD survey tool may record the continuous survey data as it ascends within the previously drilled section of the wellbore. The continuous survey data may be used to generate a continuous survey of the wellbore, which may be used to determine the true path or trajectory of the wellbore.

Gyro-while-Drilling (GWD) Survey Tool

As explained above with respect to FIGS. 1A and 1B, a system 100 may include a survey tool 120 and a processor 130. In particular, the survey tool 120 may be a GWD survey tool disposed in a wellbore 112, and the processor 130 may be a computing system. The computing system 130 is described in further detail in a later section. As shown, the GWD survey tool 120 may be part of a tool string 110 (hereinafter referred to as a drill string 110). In particular, the GWD survey tool 120 may be disposed in a downhole portion of the drill string 110, such as a bottom hole assembly (BHA) of the drill string 110.

The GWD survey tool 120 may include at least one gyroscopic sensor module 122 (hereinafter referred to as one or more gyroscopic sensors 122) and at least one accelerometer module 124 (hereinafter referred to as one or more accelerometers 124). The GWD survey tool 120 may also include any other sensors and/or instrumentation known to those skilled in the art.

As noted above with respect to the gyroscopic sensor modules of FIGS. 1A and 1B, the one or more gyroscopic sensors 122 of the GWD survey tool 120 can be any gyroscopic sensor known to those skilled in the art, including those mentioned above. In particular, as is known to those skilled in the art, the gyroscopic sensors 122 may be configured to provide measurements of the Earth's rotation rate with respect to two or three orthogonal axes of the GWD survey tool 120. The gyroscopic sensors 122 may also be configured to provide measurements of change in inclination and azimuth of the GWD survey tool 120 (i.e., orientation of the tool) over relatively short depth intervals. In one implementation, the one or more gyroscopic sensors 122 may include three single-axis gyroscopic sensors or two dual-axis gyroscopic sensors, and may be used to provide measurements of the Earth's rotation rate with respect to the x, y, and z axes of the survey tool 120.

As also noted above with respect to the accelerometer modules of FIGS. 1A and 1B, the one or more accelerometers 124 of the GWD survey tool 120 can be any accelerometer known to those skilled in the art, including those mentioned above. In particular, as is known to those skilled in the art, the one or more accelerometers 124 may include three single-axis accelerometers configured to provide measurements of the orthogonal components (g_x, g_y, g_z) of the Earth's gravitation vector with respect to the x, y, and z axes of the survey tool 120.

In conventional systems, the GWD survey tool 120 may be used to acquire survey data while the drill string 110 is drilling the wellbore 112 and being extended downwardly along the wellbore 112. In particular, the GWD survey tool 120 may be used to acquire gyrocompassing survey data (i.e., stationary survey data) during an inrun data acquisition using the one or more gyroscopic sensors 122 and the one or more accelerometers 124, as described in earlier sections. As noted above, an inrun data acquisition may refer to a data acquisition performed as a survey tool is inserted into a wellbore. However, the situation downhole may not be known precisely, and failure of the GWD survey tool 120 to become stationary when survey data are collected during the inrun data acquisition may degrade the accuracy of a wellbore survey generated using this survey data.

As such, various implementations described herein may be used to acquire continuous survey data during an outrun data acquisition using the GWD survey tool 120, where the continuous survey data may be used to generate a continuous survey of a previously drilled section of the wellbore 112 in order to determine the true path or trajectory of the previously drilled section of the wellbore 112.

The acquisition of the continuous survey data by the GWD tool 120 differs from the gyrocompassing surveys provided by the tool in that, while acquiring the continuous survey data, the tool is configured to measure changes in the orientation of the tool and to the Earth's rotation rate. The measured changes in the orientation of the tool can be integrated by a computing system in order to generate a continuous survey (i.e., azimuth and inclination) of the wellbore. As explained above with respect to FIGS. 1A and 1B, in some implementations, the same gyroscopic sensors 122 may be used for acquiring either the continuous survey data or the stationary survey data. In other implementations, different gyroscopic sensors 122 may be dedicated to acquiring either the continuous survey data or the stationary survey data.

In particular, after a period of drilling using the drill string has ceased, the GWD survey tool 120 may be disposed in the previously drilled section of the wellbore 112. A portion of the drill string may be retrieved thereafter, such as to inspect and/or repair a portion of the BHA, as similarly described above with respect to FIG. 7. This retrieval process may also be referred to as a “tripping out of hole” procedure, by which the BHA, including the drill bit and the GWD survey tool 120, is brought to the surface a section of drill string 110 at a time.

As such, during the retrieval of the drill string 110, the GWD survey tool 120 is raised within the wellbore 112 to the surface or to a higher position within the wellbore, placing the GWD survey tool 120 at multiple positions of different depths with respect to the Earth as the drill string ascends the wellbore 112.

Accordingly, the GWD survey tool 120 may be configured to acquire continuous survey data during an outrun data acquisition as the drill string 110 is being retrieved from the wellbore 112, during which the tool 120 may record the continuous survey data at the multiple positions (i.e., survey stations) within the wellbore 112 and store that data in an electronic memory device (not pictured) of the GWD survey tool 120. The data recorded by the tool 120 as the tool 120 ascends the wellbore 112 may correspond to continuous survey measurements acquired using the one or more gyroscopic sensors 122, the one or more accelerometers 124, and any other sensors of the GWD survey tool 120.

In particular, the survey data may be acquired using these sensors at discrete intervals (i.e., survey stations) as the drill string is being retrieved from the wellbore 112. Although the survey data is acquired at discrete intervals, the discrete intervals may be set to a value such that the survey data effectively corresponds to “continuous” survey data for a previously drilled section of the wellbore 112. As such, the survey data acquired using the implementations discussed herein are referred to as “continuous survey data”.

For example, the discrete intervals may be set to be no greater than every one foot along the wellbore 112. In other examples, discrete intervals of three feet, five feet, and so forth may be used. A data sampling (i.e., acquisition) frequency of the GWD survey tool 120 may be set to a particular value in order to assure that the survey tool 120 acquires the continuous survey data at particular discrete intervals (e.g. every one foot). The setting of the data sampling frequency of the tool 120 may depend on the rate of ascent of the tool 120 within the drill string. In particular, the faster that the tool 120 moves within the drill string, the higher the data sampling frequency should be in order to assure that the GWD survey tool 120 acquires the continuous survey data at the particular discrete intervals.

In one implementation, the continuous survey data may be used to determine a toolface angle, an inclination angle, and azimuth for each survey station along the wellbore as the tool 120 ascends within the wellbore 112. In another implementation, the continuous survey data may include measured changes in inclination and azimuth between each survey station along the wellbore as the tool 120 ascends within the wellbore 112.

In addition, the continuous survey data also includes depth data acquired by the GWD survey tool 120 during the outrun data acquisition. In one implementation, the depth of the GWD survey tool 120 (i.e., the depth data) at the survey stations for the continuous survey data recorded during the outrun data acquisition can be determined based on the known lengths of the drill string 110 and of each section of the drill string 110 that is pulled out during the retrieval process.

In one such implementation, in addition to the known lengths of the drill string 110 and of each section of the drill string 110 that is pulled out during the retrieval process, the depth of the GWD survey tool 120 (i.e., the depth data) at the survey stations can be determined based on the assumption that the rate of ascent of the drill string 110 during retrieval is substantially constant, particularly between the multiple stationary positions at which the GWD survey tool 120 is placed during the retrieval process described above with respect to FIG. 7. In another implementation, in addition to the known lengths of the drill string 110 and of each section of the drill string 110 that is pulled out during the retrieval process, the depth of the GWD survey tool 120 (i.e., the depth data) at the survey stations can also be determined using the one or more accelerometers 124. In particular, the one or more accelerometers 124 may include a z-axis accelerometer configured to provide measurements of the acceleration along a longitudinal axis (i.e., z-axis) of the GWD survey tool 120. As such, the z-axis accelerometer may be used to determine the depth of the GWD survey tool 120 at the survey stations for the continuous survey data, irrespective of the rate of ascent for the tool 120 during retrieval. Specifically, the measurements acquired using the z-axis accelerometer may be integrated in order to determine the depth of the GWD survey tool 120 at the survey stations.

In one implementation, prior to the retrieval of the GWD survey tool 120, a computing system (not shown) of the GWD survey tool 120 may receive a mode signal indicating that the survey tool is to switch to a continuous survey mode, during which the continuous survey data can be acquired. In a further implementation, the computing system 130 may transmit the mode signal to the computing system of the GWD survey tool 120. The computing system 130 is discussed in further detail in a later section.

The mode signal may be communicated to the GWD survey tool 120 using any form of downhole communication known to those skilled in the art. In one implementation, the mode signal may be transmitted to the GWD survey tool 120 using mud pulse telemetry. For example, the computing system 130 may use a pulser unit to transmit the mode signal by varying the drilling fluid (mud) pressure inside the drill string. Downhole pressure transducers may measure these pressure fluctuations (pulses) and pass an analog form of the mode signal to the computing system of the GWD survey tool 120, where the received analog signal may be digitized. Other forms of downhole communication used to transmit the mode signal to the computing system of the GWD survey tool 120 may include any form of electromagnetic communication, acoustic communication, and/or the like known to those skilled in the art.

In some implementations, the GWD survey tool 120 may initially be in a stationary survey mode, during which the GWD survey tool 120 is configured to acquire stationary survey data during the inrun data acquisition. In such implementations, the mode signal may be used to switch the GWD survey tool 120 from the stationary survey mode to the continuous survey mode prior to the retrieval of the GWD survey tool 120 and the outrun data acquisition.

As explained above, the computing system 130 may be used to process the data acquired by the GWD survey tool 120 during the outrun data acquisition. In particular, based on the acquired data, the computing system 130 may be used to generate a continuous survey of the wellbore 112. As noted above, in one implementation, the computing system 130 may use the continuous survey data to determine a toolface angle, an inclination angle, and azimuth for each survey station along the wellbore 112. In a further implementation, the computing system may generate a continuous survey of the previously drilled section of the wellbore by plotting the determined azimuth and inclination angle versus depth for all of the survey stations. The continuous survey may then provide information regarding the trajectory, and thus tortuosity, of the previously drilled section of the wellbore.

In one implementation, the computing system 130 may be located at the surface, and may be configured to receive or download the recorded data from the tool 120 after the tool 120 has been retrieved from the wellbore 112 using any form of communications known to those skilled in the art. In another implementation, the computing system 130 may be configured to receive or download the acquired data from the tool 120 in real-time or near real-time as the tool 120 traverses the wellbore 112, such as through the communication implementations described above for transmitting the mode signal. The computing system 130 can include any computing system implementation known to those skilled in the art, including the processors described above with respect to FIGS. 1A and 1B. Various implementations of the computing system 130 and the computing system of the GWD survey tool 120 are further discussed in a later section.

Method

FIG. 10 illustrates a flow diagram of a method 1000 for generating a continuous survey of a wellbore in accordance with implementations of various techniques described herein. In one implementation, method 1000 may be at least partially performed by a computing system, such as the computing system 130 discussed above. It should be understood that while method 1000 indicates a particular order of execution of operations, in some implementations, certain portions of the operations might be executed in a different order. Further, in some implementations, additional operations or steps may be added to the method 1000. Likewise, some operations or steps may be omitted.

At block 1010, the computing system may receive continuous survey data acquired during an outrun data acquisition of a previously drilled section of a wellbore using a GWD survey tool, where the GWD survey tool is configured to acquire the continuous survey data as the tool ascends within the previously drilled section of the wellbore during the outrun data acquisition. In particular, the continuous survey data may be data that corresponds to a plurality of continuous survey measurements acquired during the outrun data acquisition.

As noted above, the GWD survey tool may be configured to perform the outrun data acquisition as the drill string is being retrieved from the wellbore, during which the tool records continuous survey data at multiple survey stations within the wellbore and stores that data in an electronic memory device of the survey tool. As also noted above, the continuous survey data may be acquired at discrete intervals (i.e., survey stations) as the drill string is being retrieved from the wellbore. In one implementation, such intervals may be no greater than every 1 foot along the wellbore.

The continuous survey data may be acquired using one or more gyroscopic sensors, one or more accelerometers, and any other sensors of the GWD survey tool. The continuous survey data also includes depth data acquired during the outrun data acquisition, where the depth data corresponds to depth of the GWD survey tool at the survey stations for the continuous survey data. The depth data can be determined based on the known lengths of the drill string and of each section of the drill string that is pulled out during the retrieval process. In addition, prior to the retrieval of the GWD survey tool, a computing system (not shown) of the survey tool may receive a mode signal indicating that the GWD survey tool is to switch to a continuous survey mode, during which the continuous survey data can be acquired.

At block 1020, the computing system may generate a continuous survey of the previously drilled section of the wellbore based on the continuous survey data. In particular, as is known to those skilled in the art, the continuous survey data may be plotted to produce a continuous survey of the wellbore, where the continuous survey provides information regarding the trajectory, and thus tortuosity, of the wellbore. The continuous survey of the wellbore may provide information regarding the trajectory of the wellbore at the survey stations along the wellbore.

In another implementation, the continuous survey data may also include multiple measurements for the same position within the wellbore. In particular, as is known in the art, the drill string may be composed of multiple sections threadably coupled together. As such, during the retrieval of the drill string during an outrun data acquisition, one section of the drill string is pulled out of the wellbore 112 (i.e., recovered), and movement of the drill string is momentarily stabilized. The recovered section of the drill string is then unthreaded from the drill string, and the same retrieval process is repeated for subsequent sections of the drill string. Accordingly, multiple survey measurements may be acquired using the one or more gyroscopic sensors and/or the one or more accelerometers when the drill string is momentarily stabilized at a particular position in the wellbore during the retrieval process. In such an implementation, the computing system may calculate an average of these multiple measurements, and then use this average when generating the continuous survey of the wellbore.

In another implementation, the computing system may generate the continuous survey of the wellbore based on the continuous survey data acquired during the outrun data acquisition and based on the stationary survey data acquired during the inrun data acquisition. Any implementation for generating the continuous survey based on the continuous survey data and the stationary survey data may be used, such as the method for combining the continuous survey data and the stationary survey data discussed above with respect to FIGS. 1A-9.

As mentioned above, continuous surveys may be subject to measurement drifts, which can propagate and increase in size over long wellbore sections and lead to inaccuracies in inclination and azimuth. In a further implementation, the stationary survey data acquired during drilling (i.e., the inrun data acquisition), either from the GWD survey tool or from the MWD survey tool discussed above, can be combined with the continuous survey data acquired during the retrieval process (i.e., the outrun data acquisition) in order to correct possible gyro drift of the continuous survey data. In implementations using the MWD survey tool to acquire the stationary survey data, the MWD survey tool may include any combination of one or more gyroscopic sensors, one or more accelerometers, and/or one or more magnetic sensors known to those skilled in the art.

In sum, and as noted above, implementations relating to generating a continuous survey of a wellbore may be used to more accurately determine the true path or trajectory of a previously drilled wellbore. This may be particularly important for wellbores containing severe high dog-legs and sections of high tortuosity, where failure to capture such details of trajectory can lead to errors in knowledge of well locations. As noted above, an accurate determination of the trajectory of a wellbore can be used in the identification of low-tortuosity sections for permanent installation of completion or production equipment, and the identification of high-tortuosity sections in which rod guide wear sleeve equipment is to be placed to increase rod and casing life and to reduce workover frequency.

Surveys from a Moving Platform

As explained above, to determine the trajectory of a wellbore, as is known in the art, a directional survey may be performed to measure the inclination and azimuth at selected positions along the wellbore. In particular, a survey tool may be used within the wellbore to determine the inclination and azimuth along the wellbore. The survey tool may include sensors configured to perform measurements corresponding to the instrument orientation with respect to one or more reference directions and/or to the Earth's gravity, where the measurements may be used to determine an azimuth and an inclination along the wellbore.

In one implementation, as noted above, a survey tool disposed in a previously-drilled section of a wellbore may perform stationary surveys and continuous surveys to determine the azimuth and the inclination along the wellbore. For stationary surveys (i.e., gyrocompassing surveys), the survey tool may use one or more gyroscopic sensors to acquire stationary gyroscopic data corresponding to measurements of the Earth's rotation taken at discrete depth intervals along the wellbore. For example, the survey tool may acquire stationary gyroscopic data at positions within the wellbore that are spaced from one another by pipe or stand length intervals (e.g., 30-90 feet). The stationary gyroscopic data can be used to determine the orientation of the survey tool with respect to a reference vector, such as the vector defined by the horizontal component of the Earth's rate in the direction of the axis of the Earth's rotation.

For continuous surveys, the survey tool may use one or more gyroscopic sensors to acquire continuous gyroscopic data corresponding to measurements of a rotation rate of the survey tool with respect to a known initial orientation of the tool. These measurements may be taken at frequent intervals along the wellbore (e.g., every one foot). The continuous gyroscopic data can be used to determine the change in orientation of the survey tool from the known initial orientation at the frequent intervals as the survey tool traverses the wellbore. In one implementation, the known initial orientation of the survey tool can be established at a reference position in the wellbore using a stationary survey (i.e., gyrocompassing survey). As such, and as explained in earlier sections, the survey tool may perform a stationary survey and a continuous survey in conjunction in order to determine the orientation of the tool, which may ultimately be used to determine the wellbore trajectory.

Under certain circumstances, stationary surveys may be less accurate than in other circumstances. In one scenario, the accuracy of a stationary survey can be degraded when conducted from a platform that is subject to motion, as compared to being conducted from a relatively static platform. A platform subject to motion may hereinafter be referred to as a moving platform or a non-stationary platform. Moving platforms may include an offshore platform, an offshore drilling rig, an offshore ship, or the like, where these moving platforms may be subject to wave motion and/or other movements. In particular, during an operation from a moving platform, a survey tool may be subjected to platform rotational motion in addition to the Earth's rotation. Under such conditions, the tool orientation with respect to the horizontal Earth's rate vector may be difficult to determine with the precision that is possible when operating from a static platform, since the directional reference may be effectively corrupted by the platform motion. As such, the stationary gyroscopic data acquired during the operation may be inaccurate.

In various implementations further described below, a survey tool may be deployed into a previously-drilled section of a wellbore from a moving platform, where the survey tool may be deployed to a position below a predetermined depth within the wellbore (e.g., proximate to a bottom of the previously-drilled section of the wellbore) where the effects of surface motion are relatively small or negligible and where a gyrocompassing survey may be reliably conducted. The survey tool may then be used to acquire stationary survey data to determine an initial orientation of the survey tool at this position within the wellbore. The survey tool may subsequently acquire continuous survey data during an outrun data acquisition. The continuous survey data and the initial orientation determined using the stationary survey data may be used to generate a continuous survey of the wellbore, which may be used to determine the true path or trajectory of the wellbore.

The survey tool can be a drop survey tool, a wireline survey tool, a slickline survey tool, or any other survey tool known to those skilled in the art. As is known in the art, a drop survey tool may be uncoupled from the surface (i.e., the moving platform) and may be powered using one or more batteries. A slickline survey tool may also be powered using one or more batteries and may be run on a wireline into the wellbore, though the wireline may not be used for power or communication with the surface (i.e., the moving platform). A wireline survey tool may also be run on a wireline into the wellbore, and the tool may use the wireline to be powered from the surface (i.e., the moving platform) and/or for communications with systems on the surface (i.e., the moving platform) while the tool is disposed within the wellbore. As is also known in the art, the slickline survey tool and the wireline survey tool may be configured to be lowered into a wellbore, while the drop survey tool may be configured to be dropped into a wellbore.

Drop Survey Tool

As explained above with respect to FIG. 7, a survey operation 700 may be performed using a drop survey tool 720 and a computing system 730. The drop survey tool 720 may be dropped within a wellbore 712, and may also include one or more gyroscopic sensors 722 and one or more accelerometers 724. The drop survey tool 720 may be any drop survey tool known to those skilled in the art. Though not depicted in FIG. 7, the drop survey tool 720 may be dropped into the wellbore 712 from a moving platform. Further, the computing system 730 may be located on the moving platform at the surface.

The one or more gyroscopic sensors 722 of the tool 720 may be configured to generate signals indicative of measurements of the rotation rate to which the gyroscopic sensors 722 are exposed. As noted above, the one or more gyroscopic sensors 722 of the tool 720 can be any gyroscopic sensor known to those skilled in the art, including those described above with respect to the gyroscopic sensor modules of FIGS. 1A and 1B.

In particular, the gyroscopic sensors may include a spinning mass gyroscopic sensor, such as a single-axis rate integrating gyroscopic sensor or a dual-axis dynamically tuned gyroscopic sensor; an optical gyroscopic sensor, such as a ring laser gyroscopic sensor (RLG) or a fiber-optic gyroscopic sensor (FOG); a microelectromechanical system (MEMS) gyroscopic sensor; and/or any other implementation known to those skilled in the art. In particular, the one or more first gyroscopic sensors 722 may include one or more dual-axis gyroscopic sensors, one or more single-axis gyroscopic sensors, or combinations thereof that are configured to provide measurements of the Earth's rotation rate about the x-axis, the y-axis, or the z-axis of the drop survey tool 720.

In one implementation, the gyroscopic sensors 722 used in the survey tool may include a type of solid state sensor referred to as a Coriolis vibratory gyroscopic (CVG) sensor. CVG sensors may include a tuning fork gyroscopic sensor, a hemispherical resonator gyroscopic sensor (HRG), and/or any other form of CVG sensors known in the art. As is known in the art, CVG sensors may use a vibrating element to determine a rate of rotation. In particular, a basic principle of operation of such sensors is that the vibratory motion of the vibrating element may create an oscillatory linear velocity. If the sensor is in the presence of a rotational field, a Coriolis acceleration may be induced. This acceleration may modify the nature of the vibrating element, and this change can be detected and used to determine the magnitude of the applied rotation.

In some implementations, CVG sensors may be more suitable for use in a survey tool 720 when compared to other types of gyroscopic sensors, such as conventional mechanical gyroscopic sensors (e.g., conventional spinning mass gyroscopic sensors). In particular, when compared to other gyroscopic sensors, CVG sensors may have a relatively rugged construction and may be able to withstand applied accelerations of many tens of thousands of g-forces. Further, CVG sensors may be less susceptible to g-dependent effects, and thus may lessen the effect that g-dependent errors may have on survey accuracy, particularly when compared to conventional mechanical gyroscopic sensors. Further, with respect to wellbore surveying and construction, the application of CVG sensors may lead to: a reduction in the physical size of survey tools incorporating these sensors; a reduction in power requirements; reduced survey time, as spinning mass gyroscopes take time for the rotor to reach the required spin speed; and increased time intervals between recalibrations of the survey tool.

The one or more accelerometers 724 may be configured to measure one or more orthogonal and/or non-orthogonal components of the Earth's gravity, where these measurements may be used to generate an inclination angle and a toolface angle of the drop survey tool 720, as is known to those skilled in the art. In particular, the one or more acceleration sensors 724 may include one or more dual-axis or one or more single-axis accelerometers configured to provide measurements of the orthogonal components (g_x, g_y, g_z) of the Earth's gravitation vector with respect to the x, y, and z-axes of the drop survey tool 720. Various types of accelerometers may be used, including those described above with respect to the accelerator modules of FIGS. 1A and 1B. The drop survey tool 720 may also include any other sensors and/or instrumentation known to those skilled in the art.

In another implementation, the drop survey tool 720 may be smaller in size and/or weight than conventional MWD or GWD survey tools known to those skilled in the art. In particular, in such implementations, the drop survey tool 720 may be configured with a length and weight such that an individual may be capable of physically carrying the survey tool. In one such implementation, the drop survey tool 720 may have a length that is equal to less than ten feet. In another such implementation, the drop survey tool 720 may have a length that is equal to approximately three feet. In one such implementation, the drop survey tool 720 may have gyroscopic sensors 722 that include one or more solid state CVG sensors, where the x and y gyroscopic sensors (of the gyroscopic sensors 722) may be mounted with the x and y accelerometers (of the accelerometers 724) in a single chassis unit (not pictured) which can be rotated together. The orientation of this unit within the survey tool 720 may be controlled by a motor drive unit (not pictured) mounted alongside the xy sensor chassis unit. A z gyroscopic sensor (of the gyroscopic sensors 722) may be mounted separately.

As noted above, the drop survey tool 720 may be used to perform stationary surveys (i.e., gyrocompassing surveys) and continuous surveys to determine the azimuth and the inclination along the wellbore 712. In one implementation, to perform these surveys from a moving platform, the drop survey tool 720 may initially be deployed into a previously-drilled section of the wellbore 712 from the moving platform, where the survey tool 720 may be deployed to a position below a predetermined depth within the wellbore 712.

The drop survey tool 720 may then be used to acquire stationary survey data (i.e., gyrocompassing survey data) at this position within the wellbore 712, where the stationary survey data may be used to determine an initial orientation of the survey tool 720. The drop survey tool 720 can then acquire continuous survey data during an outrun data acquisition. Using the continuous survey data and the initial orientation, a continuous survey of the wellbore may be generated. As described above, an outrun data acquisition may refer to a data acquisition performed as a survey tool is extracted from at least the previously drilled section of the wellbore (e.g., as the survey tool is withdrawn from the previously drilled section of the wellbore to the moving platform at the surface).

In one implementation, the predetermined depth may correspond to a depth in the wellbore below which the effects of the platform motion on the gyroscopic sensors 722 may be minimized during a stationary survey (i.e., gyrocompassing survey). In particular, below the predetermined depth, the effects of the motion of the moving platform on the one or more gyroscopic sensors 722 may be acceptably small, such that the tool orientation with respect to the horizontal Earth's rate vector may be determined using the sensors 722 with at least a minimum level of precision and/or accuracy.

In one implementation, to deploy the drop survey tool 720 to the position below the predetermined depth within the wellbore 712, the tool 720 may be dropped into a drill string (not pictured) of the wellbore 712. In particular, the drop survey tool 720 may be configured to land at the bottom of the drill string, at which point the tool 720 may be stationary and positioned below the predetermined depth. This position may be in an area proximate to a bottom hole assembly (BHA) of the drill string and/or proximate to a bottom of the previously-drilled section of the wellbore.

As mentioned above, the drop survey tool 720 may include a spring mounted to the bottom of the tool and/or any other implementation known in the art that may be used to minimize levels of shock and vibration for the tool 720 as it lands within the drill string at the bottom of the previously drilled section of wellbore. Further, in some implementations, the drop survey tool 720 may freefall in the drill string after it is initially dropped. However, various implementations for the drop survey tool 720 may also be used in order to control a rate of descent within the drill string, and to minimize levels of shock and vibration for the tool 720 as it travels down the wellbore and lands within the drill string. In another implementation, the drop survey tool 720 may include various mechanical components that may engage with the inner diameter of the drill string, thus slowing the rate of descent of the drop survey tool 720. In addition, as explained above, the rate of descent of the drop survey tool 720 may be controlled based on the drilling fluid being pumped in the wellbore.

In a further implementation, after reaching its position below the predetermined depth (e.g., after reaching the area proximate to bottom of the previously-drilled section of the wellbore), power may be applied to the drop survey tool 720. As mentioned above, the drop survey tool 720 may be powered using one or more batteries. In one implementation, power may be applied to the drop survey tool 720 based on motion sensed by instruments in the tool 720, or based on reduced motion sensed by instruments in the tool 720 when the tool 720 comes to a halt at the bottom of the previously drilled section the wellbore 712.

After powering on, the drop survey tool 720 may perform a stationary survey (i.e., gyrocompassing survey) at the tool's stationary position below the predetermined depth. As explained in an earlier section, during a stationary survey, the drop survey tool 720 may be configured to acquire stationary survey data (i.e., gyrocompassing survey data) at one or more stationary positions within a wellbore. As such, in one implementation, after reaching its stationary position below the predetermined depth, the drop survey tool 720 may acquire stationary survey data at the stationary position. The drop survey tool 720 may record this stationary survey data by storing the data in an electronic memory device (not pictured) in the survey tool 720.

In particular, the stationary survey data recorded by the tool 720 at the stationary position below the predetermined depth may correspond to stationary survey measurements acquired using the one or more gyroscopic sensors 722, the one or more accelerometers 724, and/or any other sensors of the survey tool 720 while the tool 720 is at its stationary position. The stationary survey data may include the stationary gyroscopic data mentioned above, where the stationary gyroscopic data is acquired using the one or more gyroscopic sensors 722. In some implementations, the tool 720 may initially be in a stationary survey mode (or gyrocompassing survey mode) after powering on, where the tool 720 may be configured to perform the stationary survey described above when set to the stationary survey mode.

In a further implementation, the stationary survey data may correspond to multiple stationary measurements acquired at the stationary position below the predetermined depth (e.g., the area proximate to bottom of the previously-drilled section of the wellbore). In such an implementation, the computing system 730 may calculate an average of these multiple measurements, and then use this average when determining an initial orientation of the survey tool at the stationary position, as further described below. In one implementation, the survey tool 720 may acquire the multiple stationary measurements while the tool 720 is set to the stationary survey mode, where the tool 720 may be set to stationary survey mode for a predetermined period of time, as further described below.

In addition, the stationary survey data also includes depth data corresponding to the depth of the drop survey tool 720 while at its stationary position below the predetermined depth. Any technique known to those skilled in the art may be used to determine the depth data for the drop survey tool 720. For example, the depth of the drop survey tool 720 can be determined based on a known depth of the area proximate to the BHA of the drill string or the bottom of the previously-drilled section of the wellbore.

After performing the stationary survey as described above, the drop survey tool 720 may be used to perform a continuous survey during an outrun data acquisition phase as it is withdrawn from the well and brought to the surface. As mentioned above, an outrun data acquisition may refer to a data acquisition performed as a survey tool is extracted from at least the previously drilled section of the wellbore.

The drop survey tool 720 may be retrieved using any implementation known to those skilled in the art. In one implementation, the drop survey tool 720 may be retrieved from the bottom of a drill string via attachment to a wire. In another implementation, as described earlier, after a period of time, a portion of the drill string may be retrieved, such as to inspect and/or repair a portion of the BHA. This retrieval process may also be referred to as a “tripping out of hole” procedure, by which the BHA, including the drill bit and the survey tool 720, is brought to the surface.

As such, during the retrieval of the drop survey tool 720, the drop survey tool 720 is raised within the wellbore 712 to the surface or to a higher position within the wellbore, placing the drop survey tool 720 at multiple positions of different depths with respect to the Earth as the drill string ascends the wellbore 712. Accordingly, the drop survey tool 720 may be configured to perform a continuous survey by acquiring continuous survey data during an outrun data acquisition as the tool 720 is being retrieved from the wellbore 712. During the retrieval, the tool 720 may record the continuous survey data at the multiple positions (i.e., survey stations) within the wellbore 712 by storing that data in the electronic memory device (not pictured) of the survey tool 720. The data recorded by the tool 720 as the tool 720 ascends the wellbore 712 may correspond to continuous survey measurements acquired using the one or more gyroscopic sensors 722, the one or more accelerometers 724, and any other sensors of the survey tool 720.

The continuous survey data may include the continuous gyroscopic data mentioned above, where the continuous gyroscopic data is acquired using the one or more gyroscopic sensors 722. In some implementations, the same gyroscopic sensors 722 may be used for acquiring either the continuous gyroscopic data or the stationary gyroscopic data. In other implementations, different gyroscopic sensors 722 may be dedicated to acquiring either the continuous gyroscopic data or the stationary gyroscopic data.

As mentioned above, the survey data may be acquired using the sensors of the tool 720 at discrete intervals (i.e., survey stations) as the tool 720 is being retrieved from the wellbore 712. Although the survey data is acquired at discrete intervals, the discrete intervals may be set to a value such that the survey data effectively corresponds to “continuous” survey data for a previously drilled section of the wellbore 712. As such, the survey data acquired using the implementations discussed herein are referred to as “continuous survey data”.

For example, the discrete intervals may be set to be no greater than every one foot along the wellbore 712. In other examples, discrete intervals of three feet, five feet, and so forth may be used. A data sampling (i.e., acquisition) frequency of the survey tool 720 may be set to a particular value in order to assure that the survey tool 720 acquires the continuous survey data at particular discrete intervals (e.g. every one foot). The setting of the data sampling frequency of the tool 720 may depend on the rate of ascent of the tool 720 within the wellbore 712. In particular, the faster that the tool 720 moves within the wellbore 712, then the higher the data sampling frequency should be in order to assure that the survey tool 720 acquires the continuous survey data at the particular discrete intervals.

As discussed in greater detail below, the continuous survey data may be used to determine a toolface angle, an inclination angle, and azimuth for each survey station along the wellbore as the tool 720 ascends within the wellbore 712. In another implementation, the continuous survey data may be used to determine measured changes in inclination and azimuth between each survey station along the wellbore 712 as the tool 720 ascends within the wellbore 712.

In addition, the continuous survey data also includes depth data acquired by the survey tool 720 during the outrun data acquisition. In one implementation, the depth of the survey tool 720 (i.e., the depth data) at the survey stations for the continuous survey data recorded during the outrun data acquisition can be determined based on the known lengths of the drill string and of each section of the drill string that is pulled out during the retrieval process. In one such implementation, in addition to the known lengths of the drill string and of each section of the drill string that is pulled out during the retrieval process, the depth of the survey tool 720 (i.e., the depth data) at the survey stations can be determined based on the assumption that the rate of ascent of the tool 720 and/or drill string during retrieval is substantially constant.

In another implementation, in addition to the known lengths of the drill string and of each section of the drill string that is pulled out during the retrieval process, the depth of the survey tool 720 (i.e., the depth data) at the survey stations can also be determined using the one or more accelerometers 724. In particular, the one or more accelerometers 724 may include a z-axis accelerometer configured to provide measurements of the acceleration along a longitudinal axis (i.e., z-axis) of the survey tool. As such, the z-axis accelerometer may be used to determine the depth of the survey tool 720 at the survey stations for the continuous survey data, irrespective of the rate of ascent for the tool 720 during retrieval. Specifically, the measurements acquired using the z-axis accelerometer may be integrated in order to determine the depth of the survey tool 720 at the survey stations.

In a further implementation, the drop survey tool 720 may include a computing system (not shown), which may switch the drop survey tool 720 between a stationary survey mode (or gyrocompassing survey mode), during which the stationary survey data can be acquired, and a continuous survey mode, during which the continuous survey data can be acquired. In one such implementation, the tool 720 may switch from the stationary survey mode to the continuous survey mode after a predetermined period of time has passed from when the tool 720 has been powered on. After the predetermined period of time, during which the tool 720 is configured to record the stationary survey data at its position below the predetermined depth, the tool 720 may be switched to the continuous survey mode. After being set to the continuous survey mode, the tool 720 may be configured to acquire continuous survey data using the one or more gyroscopic sensors 722, the one or more accelerometers 724, and/or any other sensors of the survey tool 720.

In another such implementation, the tool 720 may automatically switch from the stationary survey mode to the continuous survey mode based on the motion detected by the one or more gyroscopic sensors 722 and the one or more accelerometers 724. As explained above, the tool 720 comes to a stationary position that is below the predetermined depth in the wellbore 712 (e.g., in an area proximate to a bottom hole assembly of the drill string). When the tool 720 comes to this position, the measurements from the one or more gyroscopic sensors 722 and the one or more accelerometers 724 may stabilize, measuring only components of the Earth's rotation rate and the local gravity vector, respectively. The computing system of the tool 720 may compare the standard deviations of the measurements, monitored over a fixed period of time, against predefined tolerance levels in order to determine when the tool 720 has come to a rest in the area proximate to the bottom hole assembly of the drill string. If the computing system determines that the tool 720 is no longer stationary and has begun to be retrieved from the wellbore 712, then the tool 720 may switch to the continuous survey mode.

In a further implementation, the survey tool 720 may also periodically become stationary as the tool 720 is being extracted from the previously drilled section of the wellbore 712. For example, as is known in the art, the drill string may be composed of multiple sections threadably coupled together. As such, during retrieval, one section of the drill string is pulled out of the wellbore (i.e., recovered), and movement of the drill string is momentarily stabilized. The recovered section of the drill string is then unthreaded from the drill string, and the same retrieval process is repeated for subsequent sections of the drill string. Thus, during the retrieval of the drill string, the drop survey tool 720 positioned at the bottom of the drill string is slowly raised within the wellbore and placed in multiple stationary positions of different depths with respect to the Earth (i.e., each time a section of the drill pipe is unthreaded).

As such, as the survey tool 720 is being retrieved from the bottom of the drill string and is still positioned below the predetermined depth, the tool 720 may switch back from the continuous survey mode to the stationary survey mode as the tool 720 moves uphole within the wellbore 712 and has stabilized at a stationary position in the wellbore 712. Once the computing system determines that the tool 720 is no longer stationary and has begun to again move uphole within the wellbore 712, then the tool 720 may return to the continuous survey mode. Accordingly, the tool 720 may switch back and forth between the continuous survey mode and the stationary survey mode as the tool 720 is being retrieved and while the tool 720 is positioned below the predetermined depth. The tool 720 may acquire stationary survey data these multiple stationary positions, where this stationary data may be used to ultimately generate a continuous survey of the wellbore, as further described below. In a further implementation, once the survey tool 720 is positioned at or above the predetermined depth, the tool 720 may remain in the continuous survey mode.

The computing system 730 may be used to process the stationary survey data and the continuous survey data recorded by the survey tool 720. In particular, based on the recorded data, the computing system 730 may be used to generate a continuous survey of the wellbore, as further described below. As noted above, in one implementation, the computing system 730 may use the stationary survey data and the continuous survey data to determine a toolface angle, an inclination angle, and azimuth for each survey station along the wellbore 712. In a further implementation, the computing system may generate a continuous survey of the previously drilled section of the wellbore by plotting the determined azimuth and inclination angle versus depth for all of the survey stations. The continuous survey may then provide information regarding the trajectory, and thus tortuosity, of the previously drilled section of the wellbore.

As is also explained in an earlier section, the computing system 730 may be located at the surface, and may be configured to receive or download the recorded data from the tool 720 after the tool 720 has been retrieved from the wellbore 712. The computing system 730 can be any computing system implementation known to those skilled in the art, including the processors described above with respect to FIGS. 1A and 1B. Various implementations of the computing system 730 are also discussed in a later section.

Wireline or Slickline Survey Tool

FIG. 11 illustrates a schematic diagram of a survey operation 1100 in accordance with implementations of various techniques described herein. As shown, the survey operation may be performed using a survey tool 1120 and a computing system 1130, where the survey tool 1120 may be any wireline survey tool or slickline survey tool known to those skilled in the art. The survey tool 1120 may be lowered within a wellbore 1112 from a moving platform (not shown) using a wireline, cable, or any other mechanism known to those skilled in the art. Further, the computing system 1130 may be located on the moving platform at the surface.

As mentioned above, a slickline survey tool may be powered using one or more batteries and may be run on a wireline into the wellbore, though the wireline may not be used for power or communication with the surface (i.e., the moving platform). A wireline survey tool may also be run on a wireline into the wellbore, and the tool may use the wireline to be powered from the surface (i.e., the moving platform) and/or for communications with systems on the surface (i.e., the moving platform) while the tool is disposed within the wellbore.

The survey tool 1120 may be similar to the survey tool 720 discussed above. In particular, the survey tool 1120 may also include one or more gyroscopic sensors 1122 and one or more accelerometers 1124. The one or more gyroscopic sensors 1122 and the one or more accelerometers 1124 may be similar to those discussed above with respect to FIG. 7. The survey tool 1120 may also include any other sensors and/or instrumentation known to those skilled in the art.

Similar to the drop survey tool 720, the survey tool 1120 may be smaller in size and/or weight than conventional MWD or GWD survey tools known to those skilled in the art. In particular, in such implementations, the survey tool 1120 may be configured with a length and weight such that an individual may be capable of physically carrying the survey tool. In one such implementation, the survey tool 1120 may have a length that is equal to less than ten feet. In another such implementation, the survey tool 1120 may have a length that is equal to approximately three feet. In one such implementation, the survey tool 1120 may have gyroscopic sensors 1122 that include one or more solid state CVG sensors, where the x and y gyroscopic sensors (of the gyroscopic sensors 1122) may be mounted with the x and y accelerometers (of the accelerometers 1124) in a single chassis unit (not pictured) which can be rotated together. The orientation of this unit within the survey tool 1120 may be controlled by a motor drive unit (not pictured) mounted alongside the xy sensor chassis unit. A z gyroscopic sensor (of the gyroscopic sensors 1122) may be mounted separately.

As similarly discussed above with respect to FIG. 7, the survey tool 1120 may be used to perform stationary surveys (i.e., gyrocompassing surveys) and continuous surveys to determine the azimuth and the inclination along the wellbore 1112. In one implementation, to perform these surveys from a moving platform, the survey tool 1120 may initially be deployed into a previously-drilled section of the wellbore 1112 from the moving platform, where the survey tool 1120 may be deployed to a position below a predetermined depth within the wellbore 1112.

The survey tool 1120 may then be used to acquire stationary survey data (i.e., gyrocompassing survey data) at this position within the wellbore 1112, where the stationary survey data may be used to determine an initial orientation of the survey tool 1120. The survey tool 1120 can then acquire continuous survey data during an outrun data acquisition. Using the continuous survey data and the initial orientation, a continuous survey of the wellbore may be generated. As explained above, the predetermined depth may correspond to a depth in the wellbore below which the effects of the platform motion on the gyroscopic sensors 1122 may be minimized during a stationary survey (i.e., gyrocompassing survey).

In one implementation, to deploy the survey tool 1120 to the position below the predetermined depth within the wellbore 1112, the tool 1120 may be lowered into the wellbore 1112 or into a drill string (not pictured) of the wellbore 1112. In particular, the survey tool 1120 may be lowered toward the bottom of the wellbore 1112 or the bottom of the drill string, at which point the tool 1120 may be stationary and positioned below the predetermined depth. This position may be in an area proximate to a BHA of the drill string and/or proximate to a bottom of the previously-drilled section of the wellbore 1112.

In a further implementation, after reaching its position below the predetermined depth (e.g., after reaching the area proximate to bottom of the previously-drilled section of the wellbore), power may be applied to the survey tool 1120. In one such implementation, the survey tool 1120 is a wireline survey tool, where the power may be applied from the surface using the wireline. In another implementation, the survey tool 1120 is a slickline survey tool, where the power may be applied to the based on motion sensed by instruments in the tool 1120, or based on reduced motion sensed by instruments in the tool 1120 when the tool 1120 comes to a halt at the bottom of the previously drilled section the wellbore 1112.

After powering on, the survey tool 1120 may perform a stationary survey (i.e., gyrocompassing survey) at the tool's stationary position below the predetermined depth. In one implementation, after reaching its stationary position below the predetermined depth, the survey tool 1120 may acquire stationary survey data at the stationary position. The survey tool 1120 may record this stationary survey data by storing the data in an electronic memory device (not pictured) in the survey tool 1120. The stationary survey data may be similar to the stationary survey data discussed above with respect to FIG. 7. As similarly discussed above, in a further implementation, the stationary survey data may correspond to multiple stationary measurements acquired while the tool 1120 is at the stationary position below the predetermined depth (e.g., the area proximate to bottom of the previously-drilled section of the wellbore).

In some implementations, the tool 1120 may initially be in a stationary survey mode (or gyrocompassing survey mode) after powering on, where the tool 1120 may be configured to perform the stationary survey when set to the stationary survey mode. In addition, the stationary survey data also includes depth data corresponding to the depth of the survey tool 1120 while at its stationary position below the predetermined depth. Any technique known to those skilled in the art may be used to determine the depth data for the survey tool 1120.

After performing the stationary survey as described above, the survey tool 1120 may be used to perform a continuous survey during an outrun data acquisition phase as it is withdrawn from the well and brought to the surface. In one implementation, during the outrun data acquisition, the tool 1120 may be retrieved using the attached wireline or cable. Further, the survey tool 1120 may be configured to perform a continuous survey by acquiring continuous survey data during an outrun data acquisition as the tool 1120 is being retrieved from the wellbore 1112.

During the retrieval, the tool 1120 may record the continuous survey data at the multiple positions (i.e., survey stations) within the wellbore 1112 by storing that data in the electronic memory device (not pictured) of the survey tool 1120. The continuous survey data and the manner of acquiring the continuous survey data may be similar to that discussed above with respect to FIG. 7. In some implementations, the same gyroscopic sensors 1122 may be used for acquiring either the continuous gyroscopic data or the stationary gyroscopic data. In other implementations, different gyroscopic sensors 1122 may be dedicated to acquiring either the continuous gyroscopic data or the stationary gyroscopic data.

As discussed below, the continuous survey data may be used to determine a toolface angle, an inclination angle, and azimuth for each survey station along the wellbore as the tool 1120 ascends within the wellbore 1112. In another implementation, the continuous survey data may be used to determine measured changes in inclination and azimuth between each survey station along the wellbore 1112 as the tool 1120 ascends within the wellbore 1112.

In addition, the continuous survey data also includes depth data acquired by the survey tool 1120 during the outrun data acquisition. In one implementation, the depth of the survey tool 1120 (i.e., the depth data) at the survey stations for the continuous survey data recorded during the outrun data acquisition can be determined based on the known lengths of the wire that is pulled out during the retrieval process. The depth data may also be determined using similar implementations discussed above with respect to FIG. 7.

In a further implementation, the survey tool 1120 may include a computing system (not shown), which may switch the survey tool 1120 between a stationary survey mode (or gyrocompassing survey mode) and a continuous survey mode in a similar manner as discussed above with respect to FIG. 7. In a further implementation, as similarly discussed above with respect to FIG. 7, the survey tool 1120 may be configured to acquire stationary survey data at multiple stationary positions below the predetermined depth, where this stationary data may be used to ultimately generate a continuous survey of the wellbore, as further described below. In a further implementation, once the survey tool 1120 is positioned at or above the predetermined depth, the tool 1120 may remain in the continuous survey mode.

The computing system 1130 may be used to process the stationary survey data and the continuous survey data recorded by the survey tool 1120. In particular, based on the recorded data, the computing system 1130 may be used to generate a continuous survey of the wellbore, as further described below. As noted above, in one implementation, the computing system 1130 may use the stationary survey data and the continuous survey data to determine a toolface angle, an inclination angle, and azimuth for each survey station along the wellbore 1112. In a further implementation, the computing system may generate a continuous survey of the previously drilled section of the wellbore by plotting the determined azimuth and inclination angle versus depth for all of the survey stations. The continuous survey may then provide information regarding the trajectory, and thus tortuosity, of the previously drilled section of the wellbore.

As is also explained in an earlier section, the computing system 1130 may be located at the surface, and may be configured to receive or download the recorded data from the tool 1120 after the tool 1120 has been retrieved from the wellbore 1112. The computing system 1130 can be any computing system implementation known to those skilled in the art, including the processors described above with respect to FIGS. 1A and 1B. Various implementations of the computing system 730 are also discussed in a later section.

Method

FIG. 12 illustrates a flow diagram of a method 1200 for generating a continuous survey of a wellbore from a moving platform using a survey tool in accordance with implementations of various techniques described herein. In particular, the survey tool may be a drop survey tool, a slickline survey tool, or a wireline survey tool, as described above. While the flow diagram 1200 is described herein by reference to survey tools schematically illustrated by FIGS. 7 and 11, other survey tools described herein may also be used. In one implementation, method 1200 may be at least partially performed by a computing system, such as the computing systems 730 or 1130 discussed above. It should be understood that while method 1200 indicates a particular order of execution of operations, in some implementations, certain portions of the operations might be executed in a different order. Further, in some implementations, additional operations or steps may be added to the method 1200. Likewise, some operations or steps may be omitted.

At block 1210, the survey tool may be deployed into a previously-drilled section of the wellbore from the moving platform. In one implementation, the survey tool may be a drop survey tool, where the tool may be dropped into a drill string of the wellbore. In another implementation, the survey tool may be a wireline survey tool or a slickline survey tool, where the tool may be lowered into the wellbore using a wireline, cable, or any other mechanism known in the art.

At block 1220, the survey tool may be positioned below a predetermined depth within the wellbore. The predetermined depth may correspond to a depth in the wellbore below which the effects of the platform motion on gyroscopic sensors of the tool may be minimized during a stationary survey (i.e., gyrocompassing survey). In one implementation, the survey tool may be a drop survey tool configured to land at the bottom of the drill string, at which point the tool may be stationary and positioned below the predetermined depth. In another implementation, the survey tool may be a wireline survey tool or a slickline survey tool, where the tool may be lowered to a position below the predetermined depth within the wellbore using a wireline.

At block 1230, the survey tool may perform a stationary survey at its position below the predetermined depth within the wellbore. In particular, the survey tool may acquire stationary survey data at its stationary position. The stationary survey data recorded by the tool at the stationary position below the predetermined depth may correspond to stationary survey measurements acquired using the one or more gyroscopic sensors, the one or more accelerometers, and/or any other sensors of the survey tool while the tool is at its stationary position. In addition, the stationary survey data also includes depth data corresponding to the depth of the survey tool while at its stationary position below the predetermined depth.

At block 1240, the survey tool may perform a continuous survey during an outrun data acquisition. In one implementation, the survey tool may be retrieved during the outrun data acquisition via attachment to a wire. In another implementation, the survey tool may be retrieved during the outrun data acquisition during a tripping out of hole procedure.

In particular, the survey tool may be configured to perform a continuous survey by acquiring continuous survey data during an outrun data acquisition as the tool is being retrieved from the wellbore. The data may correspond to continuous survey measurements acquired using the one or more gyroscopic sensors, the one or more accelerometers, and any other sensors of the survey tool. In addition, the continuous survey data also includes depth data acquired by the survey tool during the outrun data acquisition.

In a further implementation, the survey tool may include a computing system, which may switch the survey tool between a stationary survey mode (or gyrocompassing survey mode), during which the stationary survey data can be acquired, and a continuous survey mode, during which the continuous survey data can be acquired.

At block 1250, the survey tool may transmit the stationary survey data and the continuous survey data to a computing system in order to generate a continuous survey of the wellbore. Any implementation known to those skilled in the art may be used by the computing system for generating the continuous survey using the continuous survey data and the stationary survey data, including those discussed above with respect to FIGS. 1A-10.

In one implementation, the survey tool may be configured to transmit the stationary survey data and the continuous survey data to the computing system after the tool has been retrieved to the surface. In a further implementation, the computing system may determine an initial orientation of the tool using the stationary survey data. As noted above, the survey tool may acquire the stationary survey data at a stationary position below a predetermined depth, where the predetermined depth corresponds to a depth in the wellbore below which the effects of the platform motion on the gyroscopic sensors of the tool may be minimized during a stationary survey (i.e., gyrocompassing survey).

Accordingly, the stationary survey data acquired by the tool at its stationary position may be more accurate than stationary survey data acquired on the moving platform at the surface. As such, the initial orientation determined by computing system using the stationary survey data acquired at the position below the predetermined depth may have an acceptable level of accuracy.

As mentioned above, the continuous survey data (and continuous gyroscopic data) may correspond to measurements of a rotation rate of the survey tool with respect to a known initial orientation of the tool, where the measurements may be taken at frequent intervals along the wellbore. In particular, the continuous survey data may be used to determine a toolface angle, an inclination angle, and azimuth at each interval along the wellbore as the tool ascends within the wellbore As such, the computing system may use the determined initial orientation of the tool and the continuous survey data to determine the change in orientation of the survey tool from the determined initial orientation as the survey tool traverses the wellbore, which may be used to generate a continuous survey of the wellbore.

In sum, implementations relating to generating a continuous survey of a wellbore may be used to more accurately determine the true path or trajectory of a previously drilled wellbore, specifically from a moving platform. This may be particularly important for wellbores containing severe high dog-legs and sections of high tortuosity, where failure to capture such details of trajectory can lead to errors in knowledge of well locations. As noted above, an accurate determination of the trajectory of a wellbore can be used in the identification of low-tortuosity sections for permanent installation of completion or production equipment, and the identification of high-tortuosity sections in which rod guide wear sleeve equipment is to be placed to increase rod and casing life and to reduce workover frequency.

Computing System

FIG. 13 illustrates a block diagram of a hardware configuration 1300 in which one or more various technologies described herein may be incorporated and practiced. The hardware configuration 1300 can be used to implement the computing systems discussed above. The hardware configuration 1300 can include a processor 1310, a memory 1320, a storage device 1330, and an input/output device 1340. Each of the components 1310, 1320, 1330, and 1340 can, for example, be interconnected using a system bus 1350. The processor 1310 can be capable of processing instructions for execution within the hardware configuration 1300. In one implementation, the processor 1310 can be a single-threaded processor. In another implementation, the processor 1310 can be a multi-threaded processor. The processor 1310 can be capable of processing instructions stored in the memory 1320 or on the storage device 1330.

The memory 1320 can store information within the hardware configuration 1300. In one implementation, the memory 1320 can be a computer-readable medium. In one implementation, the memory 1320 can be a volatile memory unit. In another implementation, the memory 1320 can be a non-volatile memory unit.

In some implementations, the storage device 1330 can be capable of providing mass storage for the hardware configuration 1300. In one implementation, the storage device 1330 can be a computer-readable medium. In various different implementations, the storage device 1330 can, for example, include a hard disk device/drive, an optical disk device, flash memory or some other large capacity storage device. In other implementations, the storage device 1330 can be a device external to the hardware configuration 1300. Various implementations for the memory 1320 and/or the storage device 1330 are further discussed below.

The input/output device 1340 can provide input/output operations for the hardware configuration 1300. In one implementation, the input/output device 1340 can include one or more display system interfaces, sensors and/or data transfer ports.

The subject matter of this disclosure, and/or components thereof, can be realized by instructions that upon execution cause one or more processing devices to carry out the processes and functions described above. Such instructions can, for example, comprise interpreted instructions, such as script instructions, e.g., JavaScript or ECMAScript instructions, or executable code, or other instructions stored in a computer readable medium.

Implementations of the subject matter and the functional operations described in this specification can be provided in digital electronic circuitry, or in computer software, firmware, or hardware, including the structures disclosed in this specification and their structural equivalents, or in combinations of one or more of them. Embodiments of the subject matter described in this specification can be implemented as one or more computer program products, i.e., one or more modules of computer program instructions encoded on a tangible program carrier for execution by, or to control the operation of, data processing apparatus.

A computer program (also known as a program, software, software application, script, or code) can be written in any form of programming language, including compiled or interpreted languages, or declarative or procedural languages, and it can be deployed in any form, including as a stand-alone program or as a module, component, subroutine, or other unit suitable for use in a computing environment. A computer program does not necessarily correspond to a file in a file system. A program can be stored in a portion of a file that holds other programs or data (e.g., one or more scripts stored in a markup language document), in a single file dedicated to the program in question, or in multiple coordinated files (e.g., files that store one or more modules, sub programs, or portions of code). A computer program can be deployed to be executed on one computer or on multiple computers that are located at one site or distributed across multiple sites and interconnected by a communication network.

The processes and logic flows described in this specification can be performed by one or more programmable processors executing one or more computer programs to perform functions by operating on input data and generating output thereby tying the process to a particular machine, e.g., a machine programmed to perform the processes described herein. The processes and logic flows can also be performed by, and apparatus can also be implemented as, special purpose logic circuitry, e.g., an FPGA (field programmable gate array) or an ASIC (application specific integrated circuit).

Computer readable media (e.g., memory 1320 and/or the storage device 1330) suitable for storing computer program instructions and data may include all forms of non-volatile memory, media, and memory devices, including, by way of example, any semiconductor memory devices (e.g., EPROM, EEPROM, solid state memory devices, and flash memory devices); any magnetic disks (e.g., internal hard disks or removable disks); any magneto optical disks; and any CD-ROM and DVD-ROM disks. The processor and the memory can be supplemented by, or incorporated in, special purpose logic circuitry.

The discussion above is directed to certain specific implementations. It is to be understood that the discussion above is only for the purpose of enabling a person with ordinary skill in the art to make and use any subject matter defined now or later by the patent “claims” found in any issued patent herein.

It is specifically intended that the claimed invention not be limited to the implementations and illustrations contained herein, but include modified forms of those implementations including portions of the implementations and combinations of elements of different implementations as come within the scope of the following claims. It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions may be made to achieve the developers' specific goals, such as compliance with system-related and business related constraints, which may vary from one implementation to another. Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure. Nothing in this application is considered critical or essential to the claimed invention unless explicitly indicated as being “critical” or “essential.”

In the above detailed description, numerous specific details were set forth in order to provide a thorough understanding of the present disclosure. However, it will be apparent to one of ordinary skill in the art that the present disclosure may be practiced without these specific details. In other instances, well-known methods, procedures, components, circuits and networks have not been described in detail so as not to unnecessarily obscure aspects of the embodiments.

It will also be understood that, although the terms first, second, etc. may be used herein to describe various elements, these elements should not be limited by these terms. These terms are only used to distinguish one element from another. For example, a first object or step could be termed a second object or step, and, similarly, a second object or step could be termed a first object or step, without departing from the scope of the invention. The first object or step, and the second object or step, are both objects or steps, respectively, but they are not to be considered the same object or step.

The terminology used in the description of the present disclosure herein is for the purpose of describing particular implementations only and is not intended to be limiting of the present disclosure. As used in the description of the present disclosure and the appended claims, the singular forms “a,” “an” and “the” are intended to include the plural forms as well, unless the context clearly indicates otherwise. It will also be understood that the term “and/or” as used herein refers to and encompasses any and all possible combinations of one or more of the associated listed items. It will be further understood that the terms “includes,” “including,” “comprises” and/or “comprising,” when used in this specification, specify the presence of stated features, integers, steps, operations, elements, and/or components, but do not preclude the presence or addition of one or more other features, integers, steps, operations, elements, components and/or groups thereof.

As used herein, the term “if” may be construed to mean “when” or “upon” or “in response to determining” or “in response to detecting,” depending on the context. Similarly, the phrase “if it is determined” or “if [a stated condition or event] is detected” may be construed to mean “upon determining” or “in response to determining” or “upon detecting [the stated condition or event]” or “in response to detecting [the stated condition or event],” depending on the context. As used herein, the terms “up” and “down”; “upper” and “lower”; “upwardly” and downwardly“; “below” and “above”; and other similar terms indicating relative positions above or below a given point or element may be used in connection with some implementations of” various technologies described herein.

While the foregoing is directed to implementations of various technologies described herein, other and further implementations may be devised without departing from the basic scope thereof. Although the subject matter has been described in language specific to structural features and/or methodological acts, it is to be understood that the subject matter defined in the appended claims is not limited to the specific features or acts described above. Rather, the specific features and acts described above are disclosed as example forms of implementing the claims.

	Number	Date	Country
Parent	15863579	Jan 2018	US
Child	16509141		US

	Number	Date	Country
Parent	15452075	Mar 2017	US
Child	15863579		US
Parent	14446140	Jul 2014	US
Child	15452075		US

System and Method for Providing a Continuous Wellbore Survey

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