Delivery apparatus, system and method

Abstract

A method of obtaining formation evaluation data includes deploying an evaluation tool string into a drill string located in a wellbore. The method can also include seating the evaluation tool string in a portion of the drill string configured to optimize formation evaluation using the evaluation tool located therein.

Description

[0001] Cross-references to related applications

[0002] This application is based on and claims priority to U.S. Provisional Application Serial No. 62 / 888,798, filed August 19, 2019, which is incorporated herein by reference in its entirety. Background Technology

[0003] This disclosure generally relates to methods for obtaining formation assessment data using an assessment tool string located within a drill string in the wellbore. Conventional formation assessment operations are performed after the drill string has been withdrawn from the wellbore, which increases operation time. Furthermore, when deploying a formation assessment tool string into the wellbore using conventional methods, there is a risk that the tool string may become stuck in the hole or be lost in the hole.

[0004] Therefore, there is a need for equipment, systems, and methods to obtain formation assessment data in an effective manner that also reduces the risk of losing formation assessment tool strings in the wellbore. Summary of the Invention

[0005] A method for acquiring formation assessment data includes deploying an assessment tool string into a drill string located in a wellbore. The method may further include setting the assessment tool string within a portion of the drill string configured to optimize formation assessment using an assessment tool located therein. The method may also include operating the assessment tool string to acquire formation assessment data as the drill string is retrieved from the wellbore. The method may further include acquiring operational data during transport, after setting, and during operation of the assessment tool; and transmitting the acquired assessment data and acquired operational data to the surface using a communication system on the assessment tool string as the drill string is retrieved from the wellbore.

[0006] A method for mooring and deploying a tool string in a drill string may include seating the tool string in a set of tubing optimized for drilling and penetration logging; wherein the tool string has a communication system to the surface for communication after disconnection.

[0007] A method for tetherless deployment of a tool string in a drill string may include seating the tool string in a set of tubing optimized for drilling and penetration logging, wherein the tool string includes a communication system to the surface. Attached Figure Description

[0008] A better understanding of the various aspects of the invention can be achieved by reading the following detailed description and referring to the accompanying drawings, in which:

[0009] Figure 1 A schematic diagram of the post-drilling logging system is depicted.

[0010] Figure 2 A schematic diagram depicting the optimized portion of the drill string is shown.

[0011] Figure 3 An example of an evaluation tool string adjacent to an optimization section is depicted, depicting alignment of the evaluation tool string with the optimization section. DETAILED DESCRIPTION

[0012] One or more specific embodiments of the present application will be described below. These described embodiments are examples of the present technology. Additionally, in an effort to provide a concise description of these embodiments, all features of an actual implementation can not be described in the specification. It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions must be made to achieve the developer's specific goals, such as compliance with system-related and business-related constraints, which can 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 in the art having the benefit of this disclosure.

[0013] A method of acquiring formation evaluation data can include deploying an evaluation tool string into a drill string located in a wellbore. The drill string is optimized for drilling and performing related operations, such as drilling, reaming, circulation, etc. The drill string while drilling has one or more sections thereof optimized for through-the-casing logging and data acquisition. Thus, the drill string having one or more sections optimized for through-the-casing logging reduces the total time to complete a drilling plan and a logging plan.

[0014] The evaluation tool string can be delivered by pumping the evaluation tool string into the drill string without the need to connect the evaluation tool string to surface equipment. In another embodiment, the evaluation tool string can be deployed with a wireline, slickline, electrical cable, etc. connected to the evaluation tool string. In one or more embodiments, the tether can be released prior to tripping the drill string out of the wellbore.

[0015] The method can also include landing the evaluation tool string in a portion of the drill string configured to optimize formation evaluation using the evaluation tool located therein. As used herein, "configured to optimize formation evaluation" can mean that the material properties in the portion of the drill string are such that the formation evaluation tool adjacent to the portion will have substantially equivalent performance to the same type of formation evaluation tool used outside of the drill string. By adjusting the size and material properties of the portion of the drill string adjacent to the tool, the same performance can be achieved. Even if the drill string causes a bias in the measurements, the bias can be characterized and the resulting measurement bias is corrected by the opposite amount to achieve the same performance as the same type of formation evaluation tool used outside of the drill string. For example, for an acoustic formation evaluation tool, the portion of the drill string configured to optimize formation evaluation can have a material with a slowness (driven by the density and Young's modulus of the material) that is offset from the slowness of the formation, allowing waves returning from the formation to be distinguished from waves returning from the drill string. Likewise, the acoustic impedance can be optimized to optimize energy transfer to and from the formation.

[0016] For a formation evaluation tool that uses gamma rays or X-rays, the portion of the drill string configured to optimize formation evaluation will be made of a low density material that ensures minimal absorption of the X-rays or gamma rays by the material. In addition, the aperture can be optimized to direct a controlled beam of gamma rays or X-rays to and from the formation. For a formation evaluation tool based on neutrons, the portion of the drill string configured to optimize formation evaluation can be made of a material with low hydrogen content. In yet another example, for an inductive formation evaluation tool, the portion of the drill string configured to optimize formation evaluation can be made of a material with low electrical conductivity, and have internal and external geometries that prevent high concentration of current near the transmitter.

[0017] Thus, the portion of the drill string optimized to enhance formation evaluation is configured to match the properties required by the particular formation evaluation tool used adjacent to the portion of the drill string. With the help of the present disclosure, one of skill in the art will know how to configure the portion of the drill string to optimize formation evaluation.

[0018] In one or more embodiments, the evaluation tool string can be conveyed with a tether, and the tether can be broken when landed in the drill string. The tool string can be configured to allow the tether to be attached thereto after landing to allow the tool string to be retrieved.

[0019] The tool string can feature a power source (e.g., a battery), a storage system (e.g., using a solid state non-volatile data storage chip), and a closed loop control capable of autonomous, battery powered logging with data recorded in memory.

[0020] The portion of the drill string configured to optimize formation evaluation can include alloy steel or stainless steel or any metallic tubing, collars, stabilizers, etc. or combinations thereof; composite collars with portions made of carbon fiber, aramid, glass, ceramic, epoxy, etc. or combinations thereof; features to assist sensors on the evaluation tool in acquiring formation data; features to position the evaluation tool string in the drill string; features to assist in uplink and downlink communication with the surface; features to assist in conveyance; features to make it more robust during the drilling phase.

[0021] In one or more embodiments, the drill string can have one or more portions optimized for formation evaluation using induction resistivity tools, the optimized portions can include collars with non-conductive composite materials, such as epoxy fiberglass or aramid epoxy-based materials. In addition, the wear pads are made of ceramic or any type of wear-resistant material.

[0022] In one or more embodiments, the drill string can have one or more portions optimized for formation evaluation using acoustic tools, the collars can use composite materials where the speed of sound of the acoustic waves propagating from the collars is different from the speed of sound of the acoustic waves propagating from the formation. The different speeds allow the waves propagating from the formation to be distinguished from the waves propagating from the collars. The collars can also use materials and manufacturing techniques that enable consistent characterization and response.

[0023] In one or more embodiments, the drill string can have one or more portions for optimization of formation evaluation using nuclear tools, the collars can be adjusted for "transparency" so that the emitted and received particles (photons, neutrons, etc.) propagate in an optimized consistent medium to enable characterization of the measurements, the particle beams are directed to the formation and back to the tool in an optimized manner.

[0024] The drill string can have at least one no-go that engages at least one feature on the tool string, for example, it positions the tool string along the drill string axis in a portion of the drill pipe optimized for logging, for example, all the emitters and receivers are positioned in an optimized manner. This can be achieved by a shoulder or internal upset in the drill string designed to be smaller than the maximum outer diameter of the tool string up to a certain length from the bottom if located above the tool string or up to a diameter restriction if located at the bottom of the tool string.

[0025] In addition, the drill string can have equipment that radially centers, eccentrically or offset each tool of known value in the collars, for example, the radial position of the tool is known and taken into account during the machining process. This can be achieved by molding, machining, adding internal features such as ribs, etc. to the collars.

[0026] In addition, the drill string can use drill pipes or collars available at the well site and adapt to length variations (due to cutting or model) by modifying the parameters of the tool string, such as adding or removing spacer tools.

[0027] The drill string can also be optimized by adding or removing collars on the drill string to accommodate logging program requirements.

[0028] In one or more embodiments, the optimized portion of the drill string can have a check near it, which can be configured to engage an upper portion of the tool string, and the tool string can have a first formation evaluation tool, such as a nuclear tool, a distance x from the upper portion, and a second formation evaluation tool, such as an acoustic tool, a distance y from the upper portion. The check can be such that when the upper portion of the tool string engages the check, the nuclear tool is located near the optimized drill string portion configured to optimize nuclear formation evaluation, and the acoustic tool is located near the optimized drill string portion for acoustic formation evaluation. The optimized drill string portion can be a portion of the drill string having material properties that enable the formation evaluation tools next to it to perform as intended. For example, if one of the formation evaluation tools is a gamma ray or X-ray tool, the optimized drill string portion can have a material of minimum density to allow transparency of the X-ray or gamma ray through the portion of the drill string adjacent to the formation evaluation tool, and if the second formation evaluation tool is a neutron formation evaluation tool, the optimized drill string portion can be a material having low hydrogen content, allowing proper transparency through the optimized drill string portion.

[0029] The tool string can be configured to communicate uplink and downlink with the surface. In one embodiment, the tool string can have internal features of known and optimized shape, where the logging tool string includes matching features to partially or completely restrict annular drilling fluid flow to a channel having flow restriction regulated by the tool string, and thus enabling mud pulse telemetry uplink and downlink.

[0030] In another embodiment, the drill string can have a non-conductive collar, and the tool string can be electrically connected at both ends, enabling electromagnetic uplink telemetry.

[0031] In one or more embodiments, the drill string can be optimized to enhance delivery, for example, the drill string can have a collared drill collar on which a landing device is positioned. The landing device can have a deceleration system to the level of deceleration experienced by the tool string at the landing.

[0032] In one or more embodiments, the response of an induction resistivity tool can be used to determine whether the tool string is landed.

[0033] The drill string can be made robust to handle forces exerted by the drilling phase. For example, the drill string can have a wear-resistant band on the outside of the composite drill collar, a coating that prevents or slows down the hydrothermal aging of the composite material; or the like.

[0034] The method can also include operating the evaluation tool string to obtain formation evaluation data as the drill string is tripped out of the wellbore; and transmitting the acquired evaluation data to the surface using a communication system on the evaluation tool string.

[0035] The method can also include obtaining operational data during conveyance, after setting, and during evaluation of the tool string; and transmitting the obtained evaluation data and the obtained operational data to the surface using a communication system on the evaluation tool string as the drill string is tripped out of the well. The obtained operational data can be health data of the tool string, operational status of components of the tool string, conveyance status, downhole pressure, temperature, or other borehole condition data, etc.

[0036] The evaluation tool string can include one or more nuclear measurement tools, one or more resistivity measurement tools, one or more dielectric measurement tools, one or more sonic measurement tools, one or more magnetic resonance measurement tools, one or more survey measurement tools, or combinations thereof.

[0037] In one or more embodiments, the nuclear measurement tools obtain measurements including: natural gamma rays, spectral gamma rays, neutron porosity, rock density, neutron gamma density, spectral, x-ray density, pulsed neutron measurements, nuclear magnetic resonance, or combinations thereof.

[0038] In one or more embodiments, the sonic and / or ultrasonic measurement tools can obtain measurements including: borehole imaging, monopole, dipole, array sonic measurements, or combinations thereof.

[0039] In one or more embodiments, the survey measurement tools include one or more gyroscopes, one or more accelerometers, one or more magnetometers, or combinations thereof.

[0040] In one or more embodiments, the operational evaluation tool string is operated to obtain formation evaluation data as the drill string is tripped out of the borehole, including operating a litho-density measurement tool calibrated for through-the-casing logging. Conventional litho-density tools include a pad with a probe body having a certain mechanical freedom. The pad applied against the borehole wall houses a chemical radiation source, a detector (crystal and photomultiplier tube), and front-end electronics. The pad also contains shielding material intended to control the emission from the source and into the particle beam to the detector, for example, emitted particles react with a controlled volume of the formation, and only a controlled portion of the resulting particles are sensed by the detector. Unlike conventional litho-density, which is applied against the borehole wall with the pad, in the current embodiment, the measurement tool will be in the drill collar, so the particle beam will have to pass through the drill collar and drilling fluid before reaching the formation, so the shielding material on the pad is shaped to shoot the particle beam at the formation and back to the probe.

[0041] Figure 1A schematic of a well after drilling system is depicted. The system includes a drill string 110. The drill string 110 can be located in a wellbore after a drilling or cleanout operation of the wellbore is performed. The system also includes an evaluation tool string 120 disposed in the drill string 110, which is seated in an optimized portion 112 of the drill string. The drill string also has a bottom hole assembly connected thereto. The bottom hole assembly can include a MWD tool, a LWD tool, a RSS tool, a mud motor, a drill bit, or combinations thereof.

[0042] Figure 2 A schematic of an optimized portion of a drill string is depicted. The optimized portion 112 can include a first set of components 220. The components in the first set of components can be tubulars, drill collars, or combinations thereof. The optimized portion 112 of the drill string can also include a second set of components 224. The components in the second set of components can be tubulars, drill collars, or combinations thereof. The first set of components and the second set of components can include components made of composite materials, carbon fiber reinforced composite materials, glass fiber reinforced composite materials, alloys, or the like.

[0043] Figure 3 An example of an evaluation tool string proximate to an optimized portion is depicted, depicting the alignment of the evaluation tool string with the optimized portion. The evaluation tool string 120 is shown proximate to the optimized portion 112 of the drill string, although for clarity is shown proximate, in operation the evaluation tool string will reside within the optimized portion 112 of the drill string. The evaluation tool string can have a first series of sensors 320 and a second set of sensors 322. The first series of sensors 320 can be proximate to the first set of components 320, and the first set of components can be arranged to optimize the ability of the sensors 320 to obtain evaluation data. The second series of sensors 322 can be proximate to the second set of components, and the second set of components 224 can be arranged to optimize the ability of the sensors 322 to obtain evaluation data.

[0044] Generally, the drill string features two composite drill collars, two standard drill pipes, and a top seating drill collar. The tool string can include one or more of a resistivity tool, an acoustic tool, a litho density tool, a neutron porosity tool, a spectroscopic gamma ray tool, a natural gamma ray tool, a memory and battery system, a seating assembly on the seating drill collar, a mud pulse telemetry system, and a tractor device. In a second configuration, the tool string can include one or more of a resistivity tool, an acoustic tool, a litho density tool, a neutron porosity tool, a pulsed neutron tool, a spectroscopic gamma ray tool, a natural gamma ray tool, a memory and battery system, a seating assembly on the seating drill collar, a mud pulse telemetry system, and a tractor device.

[0045] Although example components, methods, and systems are described herein, the scope of coverage of this patent is not limited thereto. On the contrary, this patent covers every method, apparatus, and article fully described herein, including literal claims and those claims dibable under 35 U.S.C. § 1 37(c).

Claims

1. A method for obtaining stratigraphic assessment data, comprising: a. Deploy the evaluation tool string into a drill string removably located in the wellbore, and allow the evaluation tool string to pass internally through the drill string removably located in the wellbore, wherein the drill string includes a bottom hole assembly with a drill bit, and the evaluation tool string includes a first formation evaluation tool and a second formation evaluation tool; b. The evaluation tool string is seated in a portion of the drill string, the portion of the drill string being configured to optimize formation assessment using an evaluation tool located therein, such that after the evaluation tool string has been internally passed through the drill string, a first formation assessment tool and a second formation assessment tool of the evaluation tool string are positioned within corresponding first and second components of the portion of the drill string, wherein the evaluation tool string is coupled internally to the drill string, the first component includes a first material configured to enable optimization of formation assessment by the first formation assessment tool, and the second component includes a second material configured to enable optimization of formation assessment by the second formation assessment tool; c. When the drill string is pulled out of the well, operate the assessment tool string to obtain formation assessment data, including data obtained through the first and second formation assessment tools; d. Acquire operational data during transport, after placement, and during the operation of the evaluation tool column; and e. When the drill string is pulled out of the well, the acquired formation assessment data and acquired operational data are transmitted to the surface equipment using the communication system on the assessment tool string.

2. The method according to claim 1, wherein, Deploying the evaluation tool string into the drill string includes pumping the evaluation tool string into the drill string without connecting it to ground equipment via a tether.

3. The method according to claim 1, wherein, Deploying the evaluation tool string into the drill string includes pumping the evaluation tool string into the drill string using a tether connected to the evaluation tool string.

4. The method of claim 3, further comprising releasing the tether from the evaluation tool post after the evaluation tool post has been placed.

5. The method according to claim 1, wherein, At least one of the first stratigraphic assessment tool and the second stratigraphic assessment tool includes one or more nuclear measurement tools, one or more resistivity measurement tools, one or more acoustic measurement tools, one or more magnetic resonance measurement tools, one or more survey measurement tools, one or more auxiliary or adapter head tools; or a combination thereof.

6. The method according to claim 5, wherein, The measurements obtained by the nuclear measurement tools include: natural gamma rays, energy-spectral gamma rays, neutron porosity, rock density, neutron gamma density, spectroscopy, X-ray density, pulsed neutron measurements, nuclear magnetic resonance, or a combination thereof.

7. The method according to claim 5, wherein, Measurements obtained by acoustic measurement tools include: borehole imaging, monopole, dipole, array acoustic measurements, or combinations thereof.

8. The method according to claim 5, wherein, The surveying and measuring tools include one or more gyroscopes, one or more accelerometers, one or more magnetometers, or combinations thereof.

9. The method according to claim 5, wherein, Auxiliary or adapter head tools include one or more swivels, one or more centralizers, one or more universal joints, one or more eccentrics, one or more steering knuckles, one or more gaskets, or combinations thereof.

10. The method according to claim 1, wherein, Operating the assessment tool string to obtain formation assessment data when the drill string is pulled out of the well includes operating a calibrated lithology density measurement tool with sources and detectors optimized for through-tube logging and forming a controlled aperture.

11. A method for securing a deployment tool string in a drill string removably located in a wellbore, comprising: a. The tool string is seated in a set of fittings optimized for drilling and penetration logging, such that, after the tool string has passed internally through the drill string, a first formation assessment tool and a second formation assessment tool of the tool string are positioned within corresponding first and second components of the set of fittings of the drill string, wherein the tool string is connected internally to the drill string, the first component includes a first material configured to enable formation assessment through the first formation assessment tool, and the second component includes a second material configured to enable formation assessment through the second formation assessment tool; and b. Well logging through this set of tubing includes obtaining formation assessment data via corresponding first and second formation assessment tools; wherein the tool string has a communication system for communication to and from the surface for communication after disconnection from the tool string.

12. The method according to claim 11, wherein, At least one of the first stratigraphic assessment tool and the second stratigraphic assessment tool includes one or more nuclear measurement tools, one or more resistivity measurement tools, one or more acoustic measurement tools, one or more magnetic resonance measurement tools, one or more survey measurement tools, one or more auxiliary or adapter head tools; or a combination thereof.

13. The method according to claim 11, wherein, The communication system includes mud pressure telemetry, electromagnetic telemetry, ultrasonic distributed telemetry, or a combination thereof.

14. A method for deploying a tool string without tethering in a drill string, comprising: a. The tool string is seated in a set of fittings optimized for drilling and penetration logging, such that after the tool string has passed through the drill string internally, a first formation assessment tool and a second formation assessment tool of the tool string are positioned within corresponding first and second components of the set of fittings of the drill string, wherein the tool string is connected inside the drill string, the first component includes a first material configured to enable formation assessment to be optimized by the first formation assessment tool, and the second component includes a second material configured to enable formation assessment to be optimized by the second formation assessment tool; b. Well logging using this set of tubing includes obtaining formation assessment data via corresponding first and second formation assessment tools, and c. The tool post includes a communication system for traveling to and from ground equipment.

15. The method according to claim 14, wherein, At least one of the first stratigraphic assessment tool and the second stratigraphic assessment tool includes one or more nuclear measurement tools, one or more resistivity measurement tools, one or more acoustic measurement tools, one or more magnetic resonance measurement tools, one or more survey measurement tools, one or more auxiliary or adapter head tools; or a combination thereof.

16. The method of claim 14, wherein, The communication system includes mud pressure telemetry, electromagnetic telemetry, ultrasonic distributed telemetry, or a combination thereof.

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