WO2008116077A2

WO2008116077A2 - Downhole tool string component

Info

Publication number: WO2008116077A2
Application number: PCT/US2008/057677
Authority: WO
Inventors: David R. Hall; Paula Turner; Nathan Nelson; Scott Dahlgren; Jonathan Marshall; Daryl Wise
Original assignee: Hall David R; Paula Turner; Nathan Nelson; Scott Dahlgren; Jonathan Marshall; Daryl Wise
Priority date: 2007-03-21
Filing date: 2008-03-20
Publication date: 2008-09-25
Also published as: WO2008116077A3

Abstract

A downhole tool string component, having a tubular body with an outer diameter. A first, second, and third flange are disposed around the outer diameter of the tubular body at different axial locations. A first sleeve is disposed around the tubular body such that opposite ends of the first sleeve fit around at least a portion of the first and second flanges, forming a first sealed pocket around the outer diameter of the tubular body. A second sleeve is disposed around the tubular body such that opposite ends of the second sleeve fit around at least a portion of the second and third flanges, forming a second sealed pocket around the outer diameter of the tubular body.

Description

Downhole Tool String Component

BACKGROUND OF THE INVENTION

Advances in downhole telemetry systems have enable high speed communication between downhole devices and the earth's surface. With these high speed communication abilities, more downhole devices may be utilized in downhole applications. Harsh downhole environments may subject downhole devices to extreme temperatures and pressures. Further, drilling and/or production equipment may apply potentially damaging forces to the downhole devices, such as tensile loads of a drill string, compression and tension from bending, thermal expansion, vibration, and torque from the rotation of a drill string.

BRIEF SUMMARY OF THE INVENTION

In one aspect of the present invention a downhole tool string component has a tubular body with an outer diameter. A first, second, and third flange are disposed around the outer diameter of the tubular body at different axial locations. A first sleeve is disposed around the tubular body such that opposite ends of the first sleeve connect to at least a portion of the first and second flanges. A second sleeve is disposed around the tubular body such that opposite ends of the second sleeve connect at least a portion of the second and third flanges. At least one sleeve forms a pocket around the outer diameter of the tubular body.

BRIEF DESCRIPTION OF THE DRAWINGS

Fig. 1 is a cross- sectional diagram of an embodiment of a drill string. Fig. 2 is a cross- sectional diagram of an embodiment of a tool string component. Fig. 3 is a cross- sectional diagram of another embodiment of a tool string component. Fig. 4 is a cross- sectional diagram of another embodiment of a tool string component. Fig. 5 is a perspective diagram of an embodiment of a flange. Fig. 6 is a perspective diagram of an embodiment of a sleeve. Fig. 7 is a perspective diagram of another embodiment of a sleeve.

Fig. 8 is a perspective diagram of another embodiment of a sleeve.

Fig. 9 is a perspective diagram of another embodiment of a sleeve.

Fig. 10 is a perspective diagram of another embodiment of a sleeve. Fig. 11 is a perspective diagram of an embodiment of an electronics housing.

Fig. 12 is a perspective diagram of another embodiment of a sleeve.

Fig. 13 is a perspective diagram of an embodiment of a sleeve.

Fig. 14 is a perspective diagram of an embodiment of an anti- rotation assembly.

Fig. 15 is a perspective diagram of another embodiment of an anti-rotation assembly. Fig. 16 is a perspective diagram of another embodiment of an anti-rotation assembly.

Fig. 17 is a cross- sectional diagram of another embodiment of a sleeve.

Fig. 18 is a perspective diagram of another embodiment of an anti-rotation assembly.

Fig. 19 is an orthogonal diagram of another embodiment of an anti- rotation assembly.

Fig. 20 is an orthogonal diagram of another embodiment of an anti- rotation assembly. Fig. 21 is an orthogonal diagram of another embodiment of an anti- rotation assembly.

Fig. 22 is a cross- sectional diagram of an embodiment of a tool string.

Fig. 23 is a perspective view of an embodiment of an anti- rotation assembly.

Fig. 24 is cross- sectional diagram of another embodiment of a tool string component.

Fig. 25 is cross- sectional diagram of another embodiment of a tool string component. Fig. 26 is cross- sectional diagram of another embodiment of a tool string component.

Fig. 27 is cross- sectional diagram of another embodiment of a tool string component.

Fig. 28 is cross- sectional diagram of another embodiment of a tool string component.

Fig. 29 is cross- sectional diagram of another embodiment of a tool string component.

Fig. 30 is cross- sectional diagram of another embodiment of a tool string component.

DETAILED DESCRIPTION OF THE INVENTION AND THE PREFERRED

EMBODIMENT Fig. 1 is an embodiment of a drill string 100 suspended by a derrick 101. A bottom- hole assembly 102 is located at the bottom of a bore hole 103 and comprises a drill bit 104. As the drill bit 104 rotates downhole the drill string 100 advances farther into the earth. The drill string may penetrate soft or hard subterranean formations 105. The bottom- hole assembly 102 and/or downhole components may comprise data acquisition devices which may gather data. The data may be sent to the surface via a transmission system to a data swivel 106. The data swivel 106 may send the data to the surface equipment. Further, the surface equipment may send data and/or power to downhole tools and/or the bottom- hole assembly 102. A preferred data transmission system is disclosed in U.S. Patent No. 6,670,880 to Hall, which is herein incorporated by reference for all that it discloses. However, in some embodiments, no telemetry system to the surface is required. Mud pulse, short hop, or EM telemetry systems, or wired pipe may also be used with the present invention.

A downhole tool string component 200 in the drill string 100 may comprise a plurality of pockets 201, as in the embodiment of Fig. 2. The pockets 201 are formed by a plurality of flanges 202 disposed around the component at different axial locations and covered by individual sleeves 203 disposed between and around the flanges 202. A first pocket 206 may be formed around an outer diameter 204 of a tubular body 205 by a first sleeve 207 disposed around the tubular body 205 such that opposite ends of the first sleeve 207 fit around at least a portion of a first flange 208 and a second flange 209. A second pocket 210 may be formed around the outer diameter 204 of the tubular body 205 by a second sleeve 211 disposed around the tubular body 205 such that opposite ends of the second sleeve fit 211 around at least a portion of the second flange 209 and a third flange 212. A third pocket 213 may also be formed around the outer diameter 204 of the tubular body 205 by a third sleeve 214 disposed around the tubular body such that opposite ends of the third sleeve 214 fit around at least a portion of the third flange 212 and a fourth flange 215. The sleeves 203 may be interlocked or keyed together near the flanges 202 for extra torsional support. The individual sleeves 203 may allow for better axial and torsional flexibility of the component 200 than if the component 200 comprised a single sleeve spanning the pockets 201. The sleeves 203 may also comprise a plurality of grooves adapted to allow the sleeves 203 to stretch and/or flex with the tubular body 205. At least one sleeve may be made of a non- magnetic material, which may be useful in embodiments using magnetic sensors or other electronics. The pockets 201 may be sealed, though a sleeve and the pocket may comprise openings adapted to allow fluid to pass through the sleeve such that one of the pockets is a wet pocket.

Electronic equipment may be disposed within at least one of the pockets of the tool string component. The electronics may be in electrical communication with the aforementioned telemetry system, or they may be part of a closed- loop system downhole. An electronics housing 216 may be disposed within at least one of the pockets wherein the electronic equipment may be disposed, which may protect the equipment from downhole conditions. The electronics may comprise sensors for monitoring downhole conditions. The sensors may include pressure sensors, strain sensors, flow sensors, acoustic sensors, temperature sensors, torque sensors, position sensors, vibration sensors, geophones, hydrophones, electrical potential sensors, nuclear sensors, or any combination thereof. Information gathered from the sensors may be used either by an operator at the surface or by the closed- loop system downhole for modifications during the drilling process. If electronics are disposed in more than one pocket, the pockets may be in electrical communication, which may be through an electrically conductive conduit disposed within the flange separating them.

The first flange 208 may abut a first shoulder collar 300 disposed around the tubular body at a first end 302 of the tool string component 200 adapted to be a primary shoulder 301 of the component, as in the embodiment of Fig. 3. The primary shoulder

301 may provide strength and stability for the component while downhole and may prevent the sleeves 203 and flanges 202 from experiencing axial movement with respect to the component. The first shoulder collar 300 may be supported by a first left-threaded collar 303, which may be disposed around the first end 302 on a left- threaded portion 304 of the component. The left-threaded collar 303 may be keyed to the component with pins 305 in order to keep the left- threaded collar 303 axially stationary and to provide axial support to the first shoulder collar 300. The component 200 may be assembled at the drill site. The first shoulder collar

300 may be keyed to the component by a plurality of pins 305. The left- threaded collar 303 may be disposed around the component before the first shoulder collar 300 during assembly. After the left- threaded collar 303 is threaded on the component, the first shoulder collar 300 may then be slid into position from the opposite end of the component over the plurality of pins 305 which keys the component to the component.

The flanges 202 may then be placed around the component, with the first flange

208 being keyed to the primary shoulder 301, possibly by another plurality of pins 320, in order to keep the first flange 208 rotationally stationary and provide torsional support. The flanges 202 may comprise o-rings 306 disposed around an outer diameter 307 of the flanges and/or within an inner diameter 308 of the flanges 202, such that the pockets 201 may be sealed when the sleeves 203 are placed around the component. The first sleeve 207 may abut a portion of the primary shoulder 301.

The component may also be pre-assembled prior to shipping to the drill site. In such embodiments, the sleeves may be press fit around the flanges. A grit may be placed into the press fit such that the grit creates more friction between the two surfaces, wherein a stronger connection is made.

The fourth flange 215 on the component 200 may be keyed to a second shoulder collar 400 placed around a second end 401 of the component, as in the embodiment of Fig. 4. The second shoulder collar 400 may also be keyed to the component in order to provide torsional support to the sleeves 203 and electronic equipment. A second left- threaded collar 402 may also be threaded onto a left-threaded portion 403 at the second end 401 of the component and keyed to the component to prevent axial displacement of other elements around the component. The second left-threaded collar 402 may be keyed to the second shoulder collar 400 by drilling holes 406 through a length 404 of the second left-threaded collar 402 and into the second shoulder collar 400 wherein pins 305 may be inserted. A female-female connector 405 may be threaded onto the second end 401 of the component such that the component comprises a box end and a pin end for linking multiple components together.

A sleeve 203 may comprise a space 502 wherein the electronics housing 216 may be disposed, as in the embodiment of Fig. 5. The electronics housing 216 may be disposed within a portion of or all of an inner diameter 500 of the sleeve 203. A portion of the sleeve 203 and/or the electronics housing 216 may comprise bores 501 in which pins 305 may be inserted in order to key the sleeve 203 and/or housing 216 to a flange 202. The sleeve 203 may comprise recesses 600 within the inner diameter 500 wherein electronics or other elements may be disposed, as in the embodiment of Fig. 6. A flange 202 may comprise a series of lobes 700, as in the embodiment of Fig. 7. The sleeve 203 may be adapted to receive the lobes 700 such that the flange 202 provides torsional support for the sleeve 203. The flange 202 may also comprise lobes 700 on both ends or be adapted to receive lobes on both ends for connecting to a plurality of elements disposed around the component 200. A sleeve 203 and at least one flange 202 may be a single element 800, as in the embodiment of Fig. 8. The flange or sleeve may comprise a castle cut connection 801. An electronics housing 216 may also comprise a castle cut connection 801 on both ends in order to be secured to the sleeve and to receive a castle cut connection 801 from another element. The castle cut connection 801 may comprise rounded edges 802 to reduce stress risers in the connection. A flange/sleeve combination element 800 may reduce the amount of time required to assemble, and it may also increase the torsional support for the sleeve 203. Another sleeve 203 may be adapted to be pressure fit around the flange 202 of the element 800 in order to create a proper seal surrounding the pocket.

The flange or sleeve may comprise a castle cut connection 801 wherein larger portions 900 of the connection protrude and the connection is adapted to receive smaller portions of another castle cut connection, as in the embodiment of Fig. 9. The flange may comprise at least one bore 901 wherein an electrical connector 902 may be disposed such that one pocket may be electrically connected with another pocket through a conduit or conduits disposed within the flange. The electrical connector 902 may be threaded into the bore 901 and may comprise a seal to prevent materials from passing through the bore 901.

The component 200 may comprise a combination of flanges 202 which are separate from the sleeves 203 or combined with the sleeves 203, as in the embodiment of Fig. 10. Each may have advantages, depending on the type of sleeves 203 proximate the flange 202. The component 200 may comprise at least one sleeve which is a stabilizer 1000, as in the embodiment of Fig. 11. The stabilizer may comprise an outer geometry 1001 designed to stabilize the component and the drill string in the well bore while the drill string s in operation. The stabilizer 1000 may be adapted to contact the wall of the bore well. The stabilizer 1000 may also direct the flow of drilling fluid past the component.

Fig. 12 is a perspective diagram of a sleeve 2103 attached to a mandrel 2201. Fig. 12 shows a sleeve 2103 comprising an anti- rotation assembly 2270 with a castle cut geometry 2203. The anti- rotation assembly 2270 may also comprise a jagged geometry, a wave geometry, pegs, or a combination thereof. An anti-rotation assembly may aid in keeping the sleeve segments rotating with respect to each other thereby preventing some of the electronic components from twisting that may result from the drilling process. In some embodiments the electronic components may be disposed within a blade 2250 of the sleeve 2103. The blades 2250 disposed on the outer surface of the sleeve 2103 may also stabilize the tool string as it proceeds downhole. Fig. 13 is a perspective diagram of a sleeve 2103. The sleeve 2103 may comprise an anti-rotation assembly 2270 on the ends of the segments. The anti-rotation assembly 2270 may comprise a plurality of teeth 2205 on both ends of the segments extending towards each other. The anti- rotation assembly may comprise spaces 2303 between the teeth which are adapted to receive the teeth 2205 of the other segment. The anti-rotation assembly 2270 may also comprise a single tooth 2205 and single receiving space 2303. The teeth 2205 may comprise a height 2450, equal to the depth 2330 of the spaces 2303. The teeth 2205 may comprise a thickness equal to the thickness of the sleeve wall 2331. The anti-rotation assembly 2270 may be able to withstand 20,000 ft/lbs of torque. The sleeve 2103 may comprise a cylindrical seal assembly 2350 with a bore 2353 disposed around the mandrel and may be intermediate the mandrel and the sleeve segments. The seal assembly 2350 may comprise an o-ring disposed within a groove 2351. The seal assembly may be adapted to prevent fluid communication between the sleeve segments. One of the sleeves may comprise hydrophones and may be in fluid communication with the drilling mud while the other sleeve segment comprises electronic equipment requiring a dry environment. In some embodiments, the seal assembly will prevent fluid from leaking through the union of the ends of the sleeve segments to the electronic equipment. Fig. 14 is a perspective diagram of a sleeve 2103 comprising an anti- rotation assembly 2270 with a castle cut geometry 2203. Fig. 14 shows the sleeve 2103 rotating in the direction of the arrow 2405. The corners 2401 of the radial teeth 2205 may be rounded or slanted and may create a pocket 2451 when engaged to an adjacent segment of the sleeve 2103. It is believed that by having rounded corners stress risers in the sleeve 2103 will be reduced. The sides 2504 of the teeth in a castle cut geometry 2203 may be substantially parallel to the axis of the teeth 2205.

Fig. 15 is a perspective diagram of an anti-rotation assembly 270 comprising a wave geometry 2500. The anti-rotation assembly may extend around the sleeve 2103. The wave geometry 2500 may comprise teeth 2205 with sides 2504 angled outward from the axis 2550 of the tooth. The spaces 2303 intermediate the teeth 2205 may match the outline of the engaging teeth 2205 on an adjacent segment. The distance 2502 of each tooth from one another may be equal around the sleeve 2203. Fig. 16 is a perspective diagram of an anti- rotation assembly 2270 comprising pegs 2601. Segment 2252 may comprise a plurality of pegs 2601 that may engage segment 2251. Segment 2251 may comprise holes 2602 to receive the pegs 2601 from segment 2252. The pegs 2601 on segment 2252 may be large enough in diameter to create a press fit with the pegs holes 2602 on segment 2251. The pegs 2601 may comprise a diameter equal to the thickness of the sleeve wall and may extend to one inch in length. The pegs 2601 may extend at an angle relative to the sleeve 2103 or in a direction straight such as shown in Fig. 16. The pegs 2601 may be spaced equal to one another around sleeve 2103. The holes 2602 may also be evenly spaced around the sleeve 2103. A sleeve comprising pegs 2601 may provide an easy engagement and provide a proper connection between segment 2251 and segment 2252. The pegs for teeth may contain electrical connections for electronics.

Fig. 17 is a cross-sectional diagram of a sleeve 2103 comprising blades 2150 with pockets 2704. Electronic components 2701 may be disposed within the pockets 2704. The electronic components 2701 may include a Lacoste gravimeter, an absolute gravimeter, a superconducting gravimeter, gyros, computer chips, memory, electronic filters, AD/DA converters, power sources, buffers, sensors, drilling instrumentation, processors, or a combination thereof. The electronic components 2701 may be in communication with a power source 2705 such as a battery, a turbine, or a combination thereof. Fig. 17 shows segment 2251 and segment 2252 comprising an anti- rotation assembly 2270 with castle cut geometry 2203 and engaging one another.

Fig. 18 is a perspective diagram of another embodiment of an anti- rotation assembly. Segment 2251 of the sleeve 2103 may comprise teeth 2205 in a sprocket geometry 2802 radially formed around the sleeve 2103. The sleeve 2103 may also comprise indents 2801 as shown in Fig. 18. The indents 2801 may comprise a depth equal to the height of the teeth 2205 adapted to engage the indents 2801. Segment 2252 may comprise teeth 2205 extending axially from the sleeve and adapted to interlock with the indents 2801. Referring now to Fig. 19 the sleeve may comprise a segment 2251 with teeth 2205 that extend outward from the outer surface of the sleeve 2103 in a plurality of rows 2901. Segment 2252 of the sleeve 2103 may comprise a castle cut geometry 2203 adapted to receive the teeth 2205 disposed in a plurality of rows 2901. The plurality of rows 2901 of teeth 2205 may add structural support to the portions of the sleeve 2103 where the most torsional force may be applied. The rows 2901 of teeth may be disposed on segment 2251 of the sleeve 2103 and engage intermediate spaces 2303 between the teeth of a segment 2252. Segment 2252 may comprise an inner seal 2350 adapted to fit within the bore of a segment 2251. The outer diameter of the seal 2350 may be slightly smaller than the inner diameter of the sleeve 2103. The seal 2350 may comprise an inner diameter larger than the outer diameter of the mandrel.

Fig. 20 is an orthogonal diagram of another embodiment of an anti-rotation assembly. The anti- rotation assembly may comprise teeth 2205 in a jagged geometry 21000. The teeth 2205 may comprise peaks 21001 that may be offset. The jagged geometry may comprise teeth with rounded peaks 21001. The teeth 2205 may comprise a height equal to the depth of the spaces intermediate the teeth. The anti- rotation assembly may also comprise a single tooth 2205 and single receiving space 2303, such as shown in Fig. 21.

Fig. 22 is a cross-sectional diagram of a portion of a tool string 2100. The sleeve 2103 may comprise multiple segments with an anti- rotation assembly 2270. The segments of the sleeve 2103 may abutt against a shoulder element 21203 that is threadedly attached to the mandrel 2201. Threading the shoulder 21203 element onto the mandrel 2201 may axially load the sleeve 2103. The mandrel 2201 may also comprise grooves 21200 adapted to receive pins 21201 which may be disposed on the inner diameter of the sleeve 2103 and adapted to fit within the grooves 21200 of the mandrel 2201. Electronics components 2701 may be disposed within the sleeve 2103. Fig. 23 is a perspective view of an embodiment of an anti- rotation assembly 2270. The anti-rotation assembly 2270 may comprise a stress release groove 21300 on the spaces 2303 intermediate the teeth 2205. The stress release groove 21300 may aid in the manufacturing process of the anti- rotation assembly 2270. The stress release groove 21300 may also aid in preventing stress risers.

Now referring to Fig. 24, a loading member 3380 may abut one of the sleeves 3203 disposed around the tubular body 3205 at a first end 3302 of the tool string component 3200. The loading member 3380 is adapted to form a primary shoulder 3301 of the component for connection to an adjacent tool string component. The loading member may also lock the sleeve 3203 in place. In some embodiments, the loading member is threaded in a different direction than either the sleeves or thread adapted for connection to the adjacent tool string component.

The loading member 3380 may be threadedly attached to the external threadforms 3350 of a tubular body 3205. The internal threads 3305 of the loading member 3380 may comprise a first thread height 3306 that is greater than a second thread height 3307. The height differential from the first thread 3306 and second threads 3307 may comprise a .1-5 degree taper. The internal threadform 3305 and the external threadform 3350 may comprise a substantially similar spacing between each individual thread 3304. The external threadform 3350 of the tubular body 3205 may be truncated. Fig. 25 is another cross- sectional diagram of an embodiment of a tool string component 3200. The external threadform 3350 on the tubular body 3205 may comprise individual threads with the first thread 3306 comprising a greater height than the second thread 3307. Threadform 3305 comprises a plurality of threads with a substantially consistent height. When the threadforms 3350, 3305 are engaged the engagement surface diminishes from the distal thread to the proximal thread. The height differential may comprise a .1-5 degree taper. This may allow for more compliancy between the attachment of the loading member 3380 and the tubular body

3205 and may prevent breakage. The external threadforms 3350 and internal threadform 3305 may extend over half the distance of the tool string component 3200. Large amounts of torque may be applied to the tool string component 3200 in downhole conditions. The thread geometry, as shown in Fig. 25, may aid in protecting the tool string component 3200 and instrumentation in the tool string component 3200 from torsion forces. These instrumentations may be very expensive to replace and if damaged could lead to drilling delays and other possible failures. Torsion forces may travel from the proximal end 400 of the loading member 3380 through the distal end 3401 along the taper. The threadform may further comprise a relief groove 3402 that may decrease the occurrence of stress risers in the tool string. The loading member may lock into place by a tool joint 3450 of an adjacent tool string component.

Fig. 26 is another cross- sectional diagram of an embodiment of a tool string component 3200. The threadforms 3305, 3350 may extend two-thirds the length of the tool string component 3200. The threads 304 of the loading member may comprise a .1-5 degree taper and may be truncated. The internal threadform 3305 and the external threadform 3350 may be linear such as shown in Fig. 27.

Referring now to Fig. 28, the external threadform 3350 may also comprise a truncated geometry, and the internal threadform 3305 may comprise a non- truncated geometry. The threadforms may be spaced at .5-.3 inches.

Fig. 29 is another cross- sectional diagram of an embodiment of a tool string component 3200. The external threadform 3350 may comprise a castle or course thread that engages the internal threadform 3305. The external threadform 3350 may comprise a first thread 3306 with a height larger than the second thread 3307 which may comprise a taper. This geometry may spread load forces that may occur during downhole drilling and prevent premature breakage and stress fractures.

Fig. 30 discloses the geometry of the external threadform comprising a linear geometry from the proximal end 3400 of the loading member 3380 and a taper geometry extending to the distal end 3401 of the loading member 3380. The taper may be .1-5 degrees from the middle of the threadform to the shoulder. The internal threadform may comprise a linear geometry from the proximal end to the distal end.

Claims

What is claimed is: 1. A downhole tool string component, comprising: a tubular body with an outer diameter; a first, second, and third flange are disposed around the outer diameter of the tubular body at different axial locations; a first sleeve disposed around the tubular body such that opposite ends of the first sleeve connect to at least a portion of the first and second flanges; a second sleeve disposed around the tubular body such that opposite ends of the second sleeve connect to at least a portion of the second and third flanges; and at least one sleeve forming a pocket around the outer diameter of the tubular body.

2. The component of claim 1, wherein the sleeves comprise a plurality of grooves adapted to allow the sleeves to stretch and/or flex with the tubular body.

3. The component of claim 1, wherein the first pocket is electrically connected to a second pocket formed around the outer diameter of the tubular body by the second sleeve.

4. The component of claim 3, wherein the pockets are electrically connected through an electrically conductive conduit disposed within the second flange.

5. The component of claim 1, wherein at least one flange and at least one sleeve are a single element.

6. The component of claim 1, wherein an end of at least one sleeve fits around a portion of at least one flange.

7. The component of claim 1, wherein the first and second sleeves are interlocked.

8. The component of claim 7, wherein the sleeves are interlocked with a castle cut connection.

9. The component of claim 1, wherein an electronics housing is disposed within at least one of the pockets.

10. The component of claim 9, wherein the electronics housing is interlocked with at least one flange.

11. The component of claim 9, wherein the electronics housing is interlocked with the tubular body.

12. The component of claim 1, wherein at least one pocket is sealed.

13. The component of claim 1, wherein the component also comprises a collar disposed around the tubular body at an end and adapted to be a primary shoulder of the component.

14. The component of claim 1, wherein at least one sleeve is a stabilizer adapted to stabilize the component in a well bore.

15. The component of claim 1, wherein the first sleeve abuts a shoulder formed in the outer diameter of the downhole component.

16. The component of claim 1, wherein at least one sleeve is made of a non- magnetic material.

17. The component of claim 1, wherein the component comprises a third sleeve disposed around the tubular body such that opposite ends of the third sleeve connect to at least a portion of the third flange and a fourth flange, forming another pocket around the outer diameter of the tubular body.

18. The component of claim 1, wherein the tubular body comprises a shoulder near either the first or second end and being in mechanical communication with the at least first sleeve; a loading member near the other end of the tubular component is disposed about the outer surface and is adapted for loading the at least one sleeve against the shoulder; the loading member comprising an internal threadform adapted to threadingly engage an external threadform in the outer surface of the tubular body; either the external threadform or the internal threadform comprising a plurality of threads with a distal thread comprising a first thread height and a proximal thread comprising a second thread height; wherein the first thread height is greater than the second thread height and a plurality of the threads heights between the first and second thread heights accumulatively taper from the first height to the second height.

19. The component of claim 1, wherein the thread heights are truncated.