Source: http://www.google.com/patents/US5558153?dq=7,550,386
Timestamp: 2017-08-21 13:24:55
Document Index: 324590113

Matched Legal Cases: ['Art 3', 'Art-3', 'Art 7', 'Art-7', 'Art 9', 'Art-9', 'Art 4', 'Art-4']

Patent US5558153 - Method & apparatus for actuating a downhole tool - Google Patents
A downhole tool, comprising one or more separate packers and sliding sleeves in the preferred embodiment, is actuable from a nonelectrical signal transmitted from the surface to the tool. The signal is received at the tool by a control system located within the tool. The control system operates in conjunction...http://www.google.com/patents/US5558153?utm_source=gb-gplus-sharePatent US5558153 - Method & apparatus for actuating a downhole tool
Publication number US5558153 A
Application number US 08/326,824
Publication number 08326824, 326824, US 5558153 A, US 5558153A, US-A-5558153, US5558153 A, US5558153A
Inventors Michael W. Holcombe, David E. Rothers, Steve C. Owens, William D. Henderson, James C. Doane
Patent Citations (32), Non-Patent Citations (120), Referenced by (170), Classifications (11), Legal Events (4)
Method & apparatus for actuating a downhole tool
US 5558153 A
A downhole tool, comprising one or more separate packers and sliding sleeves in the preferred embodiment, is actuable from a nonelectrical signal transmitted from the surface to the tool. The signal is received at the tool by a control system located within the tool. The control system operates in conjunction with a power supply in the tool to accomplish tool actuation. In the preferred embodiment, the valve member is temporarily retained in a sealing position, isolating pressure in one chamber from a different pressure in an adjacent chamber. The valve member or piston is temporarily retained by a high-strength fiber, such as Kevlar®, in the preferred embodiment. The control system actuates the power source to heat a resistance heating wire, which causes failure in the fiber. Other mechanisms to trigger pressure-equalization can be used. The fiber can be cut by a cutter actuated electrically. The piston can be retained by solder which is melted electrically. The piston can be designed to be substantially in pressure balance so that the fiber can effectively hold the piston in place until it is rendered inoperative by heating up a resistance wire from the power supply as triggered by the control circuit. Once the fiber fails, the piston is released and the pressure is equalized. The pressure-equalization can be used to shift a setting sleeve to set a packer or to open or close a sliding sleeve valve. Different valves can be actuated in series, using different control signals, or in parallel, using one control signal. In the alternative, the same valve can be actuated to open and then to close, depending on the procedures desired. The resistance wire is threaded into the fiber cable to ensure effective transmission of the heat for proper release of the piston when desired.
1. A method of actuating a downhole tool, comprising the steps of:
retaining a member on the tool with a frangible element;
lowering the tool to the desired downhole depth;
sending at least one nonelectrical signal from the surface to the tool downhole;
receiving said nonelectrical signal at a control system mounted on the tool;
using an output generated by said control system to weaken said frangible element;
operating the tool due to movement of said member.
providing an electrical power supply on the tool;
actuating a main circuit on the tool by said control system to allow electrical current to flow from said electrical power supply to said frangible element.
heating said frangible element using current flowing in said main circuit;
causing said frangible element to fail by said heating.
forming said frangible element in the shape of a cable;
extending said cable in a manner so as to prevent movement of said member when subjected to a downhole applied force.
forming said cable from a bundle of strands;
inserting a portion of said main circuit into said strands;
breaking at least one of said strands with heat generated by a portion of said main circuit located in said strands.
using a nichrome wire for said portion of said circuit inside said strands;
using a Kevlar® material for said cable.
providing a backup circuit in said tool;
inserting portions of said backup circuit into said strands;
breaking at least one of said strands with heat generated by a portion of said backup circuit located in said strands.
unlocking at least one latch that secures the tool from actuating by movement of said member.
sending at least one acoustic signal as said nonelectrical signal.
making said control system responsive to receipt of at least one said acoustical signal;
providing a plurality of members each retained by a separate frangible element;
using said control system to weaken a plurality of frangible elements responsive to at least one said acoustical signal.
making said control system responsive to receipt of a plurality of different acoustic signals;
actuating different outputs from said control system responsive to different acoustic signals;
sequentially weakening different frangible elements using said control system to accomplish sequential movement of different members on said tool.
providing an external port on said tool to test or alter the control system after tool assembly;
providing at least one battery for use as the electrical power source in the tool.
circumscribing said member at least in part with a partial ring;
retaining said member to a detent in said tool by securing an open part of said ring with said cable;
allowing said ring to expand resulting from cable failure from said heating;
liberating said member from said detent to allow actuation of the tool.
winding on a roller at least one end of said cable on either side of said opening in said ring.
mounting said member in pressure balance;
using solder as said frangible element to obstruct a first port in the tool on one side of said member;
melting said solder with said control system;
shifting said member with an unbalanced hydrostatic force which enters said first port subsequent to said melting.
providing an initially sealed second port, on an opposite side from said first port, and in communication with said member;
breaking said initial seal on said second port by movement of said member responsive to fluid pressure applied through said first port.
making said control system responsive to receipt of at least one acoustic signal;
using said control system to weaken a plurality of frangible elements responsive to at least one signal.
a control system on said body responsive to at least one nonelectrical input signal from the surface transmitted to the tool downhole to generate at least one output signal;
at least one movable member selectively movable, with respect to said body, between a first and second position;
at least one frangible member connected to said control system and selectively retaining said movable member in said first position;
whereupon receipt of said nonelectrical signal, said control system creates an output signal, resulting in failure of said frangible member and subsequent movement of said member from said first to said second position to actuate the tool.
25. The tool of claim 24, further comprising:
an electrical source mounted in said tool;
said control system further comprises a first circuit for facilitating selective conduction of electricity from said source to said frangible member;
whereupon said conduction of electricity results in failure of said frangible member.
said frangible member is a cable;
said first circuit extending at least in part into said cable;
said portion of said circuit extending into said cable formed of a material which generates heat when electrical current flows through it.
27. The tool of claim 26, further comprising:
a backup circuit extending in part into said cable and having a portion thereof formed of a material which generates heat when electrical current flows through it;
said backup circuit operable by said control system to provide a second way to break said cable if not successfully previously broken by said control system using said first circuit.
28. The tool of claim 26, wherein:
said cable bears directly on said movable member to balance applied forces on said movable member;
whereupon breakage of said cable, an imbalance of applied forces acts on said movable member, causing it to move and actuate the tool.
29. The tool of claim 26, wherein:
said body is formed having a detent;
said movable member initially held to said detent by a partially circumscribing ring, said cable spanning a gap in said ring and initially securing said ring against said movable member to hold it to said detent;
whereupon when said control system heats said cable to failure using said first circuit, said ring expands, freeing said movable member from said detent to allow actuation of said tool.
30. The tool of claim 29, wherein:
said ring further comprises a roller mounted adjacent at least one end of said gap, said cable wound around said roller to facilitate breaking of said cable under heat applied by said first circuit.
31. The tool of claim 24, wherein:
said body comprises at least a first and second port, said ports disposed on opposed sides of said movable member and initially obstructed;
said frangible member disposed in said first port;
a shearable plug disposed in said second port;
said movable member in pressure balance when said first and second ports are obstructed;
whereupon when said control system receives said signal and produces said output signal, said frangible material alters its form responsive to said output signal, opening said first port and causing a pressure imbalance on said movable member, whereupon said movement said movable member shears said plug to open said second port for ultimate pressure re-equalization on said movable member.
32. The tool of claim 26, wherein:
said body further comprises a plurality of movable members, each retained by a frangible member;
said control system causing a plurality of frangible members to fail simultaneously responsive to a single nonelectrical input signal for operation of the tool.
33. The tool of claim 26, wherein:
said control system responding to a plurality of discrete nonelectrical signals for sequential failure of said frangible members for operation of the tool.
34. The tool of claim 33, wherein:
each said movable member selectively covers or uncovers a port through said body when moved;
whereupon through discrete nonelectrical signals, at least one port in said body may be opened and closed responsive to said nonelectrical signals.
35. The tool of claim 26, wherein:
said cable is multi-strand;
said circuit extending among said strands and formed of nichrome for said portion thereof;
said electrical source comprises at least one battery capable of raising the strand temperature by heating said nichrome wire to above 500° F. where it is sufficiently weakened so that it fails.
using a multi-strand cable;
using a control system which extends among said strands and formed of nichrome for said portion thereof;
using a control system which comprises at least one battery capable of raising the strand temperature by heating said nichrome wire to above 500° F. where it is sufficiently weakened so that it fails.
37. The tool of claim 26, wherein:
said control system is responsive to an acoustical signal input.
38. A method of actuating a downhole tool, comprising the steps of:
retaining a member on the tool with a locking element;
using an output generated by said control system to move said locking element;
operating the tool due to movement of said locking element, which movement allows said member to move.
The field of this invention relates to actuation of a downhole tool, preferably the types of tools which have a self-contained electrical power source and are actuable from the surface by nonelectrical signals.
In the past, downhole tools have been positioned in a desired location by a variety of different ways. A tubing string can be assembled at the surface with the tool at the bottom for accurate placement of the tool at the desired location. Alternatively, coiled tubing can be used as well as mechanical cables or an electric line which combines the feature of mechanical support for the tool as well as the possibility of conduction of power control signals and data to and from the surface to the electrical components in the tool downhole. One of the disadvantages of using electric line is that special equipment needs to be provided for use of the electric line. In many cases, particularly offshore, space is at a premium and it is difficult to find a suitable location for the surface equipment needed to run the electric line. Additionally, the use of an electric line, or wireline, requires not only rental of the wireline equipment but also a wireline crew to operate the equipment. It is far more desirable from an operator's standpoint to use standard rig equipment to position a downhole tool for proper downhole actuation.
As previously stated, the power could come from the surface to the final control element, such as a solenoid valve located in the tool. However, such an arrangement would require the use of a wireline and the necessary incremental cost for having a wireline crew and equipment at the rig site. When using a purely mechanical support mechanism which permits rapid placement of the tool at the desired depth, such as a cable support operated from the rig drawworks, there no longer is the ability to provide the power supply from the surface to the tool located downhole. The apparatus of the present invention illustrates a tool that can provide selective communication between two pressure zones of differing pressures, based on a low-power power supply located within the tool which is actuable from the surface by a variety of nonelectrical means. Signals may be sent from the surface mechanically through motions or impacts imparted to either a support cable or a tubing string. One such method of transmission of such signals is disclosed in U.S. Pat. Nos. 5,226,494 and 5,343,963, as well as pending applications commonly assigned Ser. Nos. 08/071,422, filed Jun. 3, 1993 (Owens), and 07/751,861, filed Aug. 28, 1991 (Rubbo), which involves production of acoustical signals which pass through a conduit wall and are detectible by a strain gauge assembly on a downhole tool, to generate a signal for actuating the downhole tool using a downhole energy source. Signals can also be acoustically transmitted through the wellbore fluids where they are sensed at the tool downhole. Regardless of how the signal is transmitted, it is received at the tool where the control circuitry closes a circuit. In the preferred embodiment, the valve member is temporarily retained by a fastening mechanism, which in the preferred embodiment is a Kevlar® cable, wrapped with a heating element. When the control circuit is actuated to provide power to a heating element, the Kevlar® cable breaks and the differential pressure across the valve member actuates the valve member, thus opening fluid communication between what had previously been two zones isolated from each other at different pressures. Thereafter, once the valve member has shifted and various seals have moved, allowing a flow opening to be created between a zone of high pressure and a zone of lower pressure, flow through the tool is initiated. This flow can be used to move a piston or a setting sleeve, making the apparatus particularly useful in setting packers, as will be described below.
A downhole tool, comprising one or more separate packers and sliding sleeves in the preferred embodiment, is actuable from a nonelectrical signal transmitted from the surface to the tool. The signal is received at the tool by a control system located within the tool. The control system operates in conjunction with a power supply in the tool to accomplish tool actuation. In the preferred embodiment, the valve member is temporarily retained in a sealing position, isolating pressure in one chamber from a different pressure in an adjacent chamber. The valve member or piston is temporarily retained by a high-strength fiber, such as Kevlar®, in the preferred embodiment. The control system actuates the power source to heat a resistance heating wire, which causes failure in the fiber. Other mechanisms to trigger pressure-equalization can be used. The fiber can be cut by a cutter. The piston can be retained by a metal or a plastic which is deformed by some means. The piston can be designed to be substantially in pressure balance so that the fiber can effectively hold the piston in place until it is rendered inoperative by degrading its integrity when triggered by the control circuit. Once the fiber fails, the piston is released and the pressure is equalized. The pressure-equalization can be used to shift a setting sleeve to set a packer or to open or close a sliding sleeve valve. Different valves can be actuated in series, using different control signals, or in parallel, using one control signal. In the alternative, the same valve can be actuated to open and then to close, depending on the procedures desired. The resistance wire is threaded into the fiber cable to ensure effective transmission of the heat for proper release of the piston when desired.
FIG. 1 is a part view of the preferred embodiment for a packer shown in the run-in position.
Referring now to FIGS. 1, 2A, and 2B, a typical packer assembly is illustrated in part. The components not mentioned are those that are familiar to a person of skill in the art. For a frame of reference, FIGS. 2A and 2B illustrate a series of slips 10, which have teeth 12 and are selectively movable outwardly into contact with a casing or formation 14. Not shown, but also included in a typical packer assembly, are one or more sealing elements, which are also actuated into contact with the casing 14 contemporaneously with the outward urging of the slips 10 to fixate the packer. In order to accomplish the setting movements necessary to set the sealing elements (not shown) and the slips 10, a setting sleeve 16 is mounted over a mandrel 18. In the run-in position shown, the setting sleeve 16 has an opening 20 through which extends a key or "locking dog"22. The key 22 extends into groove 24 in the mandrel 18. Key 22 is fixed in its position in groove 24 by virtue of piston 26, which extends between outer sleeve 28 and key 22, preventing key 22 from coming out of groove 24. Piston 26 is initially connected to key 22 by shear pin 30. Seals 32 and 34 seal, respectively, between piston 26 and outer sleeve 28 and sleeve 16. Accordingly, a cavity 36 is defined above piston 26, whereupon, as will later be explained, when a pressure build-up occurs in cavity 36, piston 26 is urged to move downwardly, shearing pin 30. Piston 26 is then able to translate with respect to setting sleeve 16 until shoulder 38 bottoms on shoulder 40 of setting sleeve 16. At that point, pressure in cavity 36 moves piston 26 in tandem with setting sleeve 16, which in turn results in setting of the slip 10 and the packing element or elements (not shown). Those skilled in the art will appreciate that more than one set of slips can be employed in packers that are known in the art. It can also be seen that when piston 26 translates with respect to setting sleeve 16, the key or locking dog 22 becomes liberated and can move radially outwardly out of groove 24, which in turn permits downward motion of setting sleeve 16. This occurs because recess 25 moves opposite key 22 at the time shoulders 38 and 40 contact.
It is important to note that during the run-in position, chamber 36, which contains the electrical components 70, is sealingly isolated from wellbore fluids found either within the mandrel 18 or in the annulus outside the outer sleeve 28, through the seals that have been previously described. As shown in FIG. 1, there is a net unbalanced force acting on piston 60. This unbalanced force is created because the pressure in chamber 56 acting on shoulder 80 creates a greater force downwardly on piston 60 than the opposing force which consists of atmospheric pressure in chamber 36 acting on shoulder 82 and lower end 68. Those skilled in the art will appreciate that the configuration of piston 60 can be adjusted to create any desired unbalanced force on the piston 60, knowing the pressures in chambers 56 and 36. The unbalanced force previously referred to is resisted by a multi-strand Kevlar® cable 84, which has windings 86 around a bolt or turnbuckle 88. The cable 84 is preferably a Kevlar® 29 Aramid braided yarn, such as can be purchased from Western Filaments, Inc., product number 500 KOR 12. This is a continuous multi-filament fiber cable braided into a round form in a tubular braid configuration with a 2-under and 2-over braid pattern on a 12-carrier braid. The cord diameter is preferably ±0.057", ±0.005", with a break strength of 500 lbs., ±10 lbs. This material is also preferred because its zero strength temperature is 850° F. and it retains 90% strength at 482° F. This fiber begins to decompose at 800° F. when tested in accordance with ASTM D276-80. Cable 84 extends through an opening 90, preferably adjacent the lower end 68 of piston 60. With that arrangement shown and the ends of the Kevlar® cable 84 tied in a knot after passing through openings 92, the piston 60 is secured against movement, thus retaining the integrity of chamber 56 with respect to passage 58 in view of seals 62 and 64.
Referring now to FIGS. 4 and 5, as well as FIG. 1, it can be seen that in the preferred embodiment, the Kevlar® cable 84, which is preferably approximately a 9"length of 500-lb. Kevlar cord, is secured to the anchors 88 by winding the cable 84 around anchor 88 after slipping it through an opening 92 reverse knot first, then tying each loose end in a knot. It is preferable to make this knot as close to the end of the cable 84 as possible with approximately 1/8 to 1/4 over-hanging beyond the knot on each end. In the preferred embodiment, an adhesive, such as that known commercially as Super Glue®, is applied to each knot. As shown in FIGS. 5 and 6, a solder tab 96 is used in several places, as shown in FIG. 4. The solder tab is rolled around the cable or cord 84 at a point approximately 2" from the knot on either end. The solder tab is wrapped around the cord 84, allowing sufficient extension on the solder tab to form a lip 98 (see FIG. 6). The lip should be long enough to allow spot welding of the tab 96 to itself. After the cord 84 is wrapped by the solder tab 96, the tab 96 should be squeezed so that it tightly wraps the cord. Thereafter, the lip 98 is spot-welded in place. Approximately 3" of nichrome wire is then cut and inserted through the cord 84 as close as possible to the battery tab 96 (see FIG. 5). The nichrome wire 102 enters the cable 84 at point 104, which is preferably as close to the battery tab 96 as possible. A sewing needle may be used to insert the wire through the cord. Preferably, all but about 3/4 of the nichrome wire 102 is pulled through the cord 84 and wrapped 3 complete turns through the cord 84 as it is woven through the cord 84 (see FIG. 5). The turns should be wrapped tightly and as close as possible without actual contact which could create a short circuit, leaving approximately 1/16" between turns so that the distance between the entry point 104 and the exit point 106 is approximately 3/16". As shown in FIG. 5, after emerging from the exit point 106, a similar configuration is used for the second solder tab 96. Leadwires 108 and 110 provide the current to an assembly shown in FIG. 5. As shown in FIG. 4, redundant assemblies are used in the event one of the assemblies fails to operate. The power that heats the nichrome wire 102 comes from the battery pack 76 (see FIG. 7) when actuated by a signal received on strain gauges 72 and 74. The receipt of the appropriate signal at strain gauges 72 and 74 triggers the control system 78 to complete a circuit from the battery pack 76 to leads 108 and 110, which in turn heats up the nichrome wire 102, causing the cord 84 to fail by thermally destroying it at this point. Piston 60 then moves under the net unbalanced force acting in chamber 56 on it (see FIG. 1). The redundant backup system triggers after a time delay, thus providing two opportunities to break cable 84. As previously stated, the signaling mechanism which triggers the printed circuit board 78 to complete the electrical circuit from the battery pack 76 to the nichrome wire 102 is a technique described in U.S. Pat. No. 5,226,494, but other nonelectrical means of communication from the surface to the control system 78 are also within the scope of the invention. The batteries of battery pack 76 are preferably lithium 3-volt Model CR12600SE Sanyo, wired to provide a terminal voltage of 6 volts. The configuration of the battery pack is described below.
The battery pack circuit board is composed of a flexible polyimide film, known as Pyralux® or Kapton®, with printed circuit wiring on or within it. These conductors provide the interconnections necessary to accomplish the parallel circuits previously described.
In this embodiment, the packer has a mandrel 130 and a setting sleeve 132, which is initially locked to it by locking dog 134. Locking dog 134 is trapped in groove 136 of mandrel 130 due to piston 138 being disposed between locking dogs 134 and outer sleeve 140 during the run-in position. During the run-in position, downward movement of piston 138 from wellbore pressure applied to it through bore 142, which communicates with piston 138 through cavity 144, is prevented due to engagement of piston 138 with block 146. Supporting block 146 is sleeve 148, which is disposed between block 146 and mandrel 130. Sleeve 148 is biased downwardly away from block 146 by a spring 150. A cord 154, preferably made of Kevlar® as previously described, extends from a collar 152. Collar 152 supports the cord 154, which extends around and is secured to sleeve 148. When shown in the run-in position as shown in FIG. 3, the cord 154 has tension in it because it is resisting the biasing force of spring 150, thus keeping the sleeve 148 in the position shown in FIG. 3 for run-in. For clarity in FIG. 3, the details of the nichrome wire assemblies described in FIG. 4 are omitted. However, such assemblies are integral to the design used as depicted in FIG. 3, in combination with the components previously described in FIG. 7 and shown in FIG. 3 schematically as 70'.
An alternative embodiment of the apparatus A is shown in FIGS. 8-11. In this application, a body 194 includes a sliding sleeve 196, which is connected to a piston 198. A chamber 200 is defined between body 194 and piston 198 and is sealed off by seals 202 and 204. The control system 220, as illustrated in Figure 7, is disposed within cavity 200. A C-shaped ring 206 extends into a groove 208 on piston 198. The details of the C-shaped ring 206 are shown in FIGS. 8 and 9. As can readily be seen, there are a pair of elongated slots 210 and 212 through which the Kevlar® cable 214, as described previously, is wound. A series of terminal screws 216 hold down the ends of the cable 214. A nichrome wire assembly 218 (shown schematically) is connected to the cable 214. The principle of operation for the causation of the failure of cable 214 is the same as previously described with the embodiment shown in FIG. 4. The C-ring 210 has a predetermined amount of stress built into it when the cable 214 is wound through elongated slots 210 and 212. In an alternative embodiment, to prevent fraying of the cable 214 as it passes through slots 210 and 212, a roller assembly 211 and 213 can be used in each slot 210 and 212 so that the cable 214 is, in fact, wound on a roller whose hub is supported adjacent the open ends of C-ring 206 and whose outer periphery passes through slot 210 or 212.
It should be noted that while the specific preferred embodiment of FIGS. 1 and 2 has been described, numerous variations fall within the purview of the invention. The invention is as broad as an application that involves actuation using stored electrical energy in a tool which is triggered by a control system which is in itself responsive to a nonelectrical signal from the surface. Thus, the surface signal can be preferably acoustic or it can be mechanical. For example, if the tool is supported by a nonelectrical cable, the signal can be generated by a sequence of motions imparted to the cable. The same result is obtained if the tool is supported by a tubing string or a coiled tubing. Alternatively, the signal can be transmitted acoustically through the well fluids either within a tubing string or a coiled tubing or on the outside in the annular space. The acoustic signal is measured at the tool by strain gauges connected to the tool which are measuring a strain response to the acoustic signal transmitted in the wellbore. The stresses within the tool are affected by the transmission of the signal in the way that a strain measurable by a pick-up device, such as the strain gauges previously described. However, other types of pick-up devices can be used so long as they are cable of processing a nonelectrical input such as strain responsive to an applied stress, physical movement, be it translation or rotation, for example. The invention is also broad enough to encompass a final controlled element, which can be reliably and predictably actuated using the stored electrical charge in, for example, the battery pack 76, previously described. That is to say, different materials other than the Kevlar® material described for cord 84 can be used without departing from the spirit of the invention. In fact, any mechanism or material which, when energized by electrical current, results in release of components which had heretofore remained in a position where they were locked from movement is within the purview of this invention. Thus, some specific examples can be the illustrations described where the electrical current flowing into solder results in a change of state in solder which allows flow to occur when the solder changes state from solid to liquid. Alternatively, the Kevlar® cable could be subject to cutting by use of a sharp object, such as a knife or a guillotine through which the Kevlar® or other type of cable passes. In this application, the electrical current can be used to actuate the cutting device which mechanically cuts the cable. The mode of failure of the retaining elements, such as a cord 84, can be varied and still be within the purview of the invention. The ultimate controlling element which keeps the components locked to each other until the control system electrically energizes the failure sequence can also be varied without departing from the spirit of the invention. A valve positioned between an actuating pressure and an internal chamber 36, which can be opened or closed by a motor or solenoid or other actuating device and controlled by electronics and battery pack is another illustration. A motor actuated by the control system and battery pack can move a mechanical link from the path of the piston to allow it to move to actuate the downhole tool.
Finally, the mode of signaling the control system to actuate the circuit to provide electrical power to ultimately unlock the components which had heretofore been locked together can be varied without departing from the spirit of the invention as long as the ultimate signaling mechanism used is one that can be readily accomplished by the drilling rig personnel without needing to involve the use of specialty equipment and oil service personnel which typically come with a wireline unit provided to a rig. Other materials than Kevlar® can be used. It is preferable that such alternative materials, if they are to be put into a failure mode by applied heat, exhibit reliable failure tendencies at predictable temperatures so that the desired actuation can occur. Heating materials other than nichrome wire are also within the purview of the invention.
FIG. 18 is an alternative embodiment of the apparatus A of the present invention. It has some similarities to the layout illustrated in FIG. 17. As shown in FIG. 18, a setting sleeve 300 for a packer or similar device is initially locked to a mandrel 302 when a latch 304 extends into groove 306, which is disposed in mandrel 302. Latch 304 is initially held captive in groove 306 by piston 308. In the run-in condition shown in FIG. 18, piston 308 is prevented from moving downwardly because latch 350 is secured to groove 351. Latch 350 is initially held captive in groove 351 by sleeve 318. When the cable 316 is wound around the segmented ring 314, the sleeve 318 cannot move; thus sleeve 318 is immobilized. Spring 320 is trying to push sleeve 318 downwardly. Sleeve 318 is prevented from moving downwardly because segmented ring 314 (see FIG. 21) is secured to groove 312 by the Kevlar® cable 316. In the manner described before for the other embodiments, the Kevlar® cable 316 is caused to fail, which causes segmented ring 314 to expand, thus allowing the force supplied by spring 320 to initiate downward movement of sleeve 318, which allows latch 350 to expand from groove 351, whereupon applied pressure through port 322 acting in cavity 324 moves piston 308 downwardly toward sleeve 318. This liberates latch 304, thus allowing the setting sleeve 300 to move upwardly with respect to the mandrel 302, thus setting the tool. The mechanism illustrated in FIGS. 18-21 can be used to set a packer or another downhole tool.
FIG. 21 illustrates in more detail the details of latch 310. There, the windings of the Kevlar® cable 316 over a segmented ring 314 are more clearly illustrated. The ring 314 includes a receptacle 340 for a rod 342. The cable 316 is secured at ends 344 and 346 by tying a knot prior to passing the end through an opening in either rod 342 at one end or ring 314 at the other end. When sufficient heat is applied to the cable 316 by the nichrome wire (not shown), the cable 316 breaks and ring 314 springs outwardly, which in turn liberates latch 310 in the manner previously described.
The preferred material for the nichrome wire is a material which can be purchased from California Fine Wire Company of Grover Beach, Calif., which is sold under the mark "Stableohm 650," material No. 100187, annealed 0.005 or 36 AWG wire, 26 ohms ±3% ohms per ft and sold under part No. WVXMMN017.
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11 * Ann Cozens, Coming Soon: A New Era in Drilling , Offshore, 78 82, Dec. 1977.
12 Ann Cozens, Coming Soon: A New Era in Drilling, Offshore, 78-82, Dec. 1977.
13 * Anthony W. Kamp, Downhole Telemetry From the User s Point of View , Journal of Petroleum Technology, 1792, Oct. 1983.
14 * Anthony W. Kamp, Downhole Telemetry From the User s Point of View , Society of Petroleum Engineers of AIME, SPE 11227, 1982.
15 Anthony W. Kamp, Downhole Telemetry From the User's Point of View, Journal of Petroleum Technology, 1792, Oct. 1983.
16 Anthony W. Kamp, Downhole Telemetry From the User's Point of View, Society of Petroleum Engineers of AIME, SPE 11227, 1982.
17 * Arnold G. Edwards, et al., New Equipment Permits Perforating, Testing, Treating and Re Testing With One Trip in the Hole, European Offshore Petroleum Conference & Exhibition, 321 325, Oct. 1978.
18 Arnold G. Edwards, et al., New Equipment Permits Perforating, Testing, Treating and Re-Testing With One Trip in the Hole, European Offshore Petroleum Conference & Exhibition, 321-325, Oct. 1978.
19 * B. J. Patton, et al., Development and Successful Testing of a Continuous Wave, Logging While Drilling Telemetry System, Journal of Petroleum Technology, 1215 1221, Oct. 1977.
20 B. J. Patton, et al., Development and Successful Testing of a Continuous-Wave, Logging-While-Drilling Telemetry System, Journal of Petroleum Technology, 1215-1221, Oct. 1977.
21 * Bernard V. Traynor, Jr., Electrodril Demonstration Program Shows Promise, MWD : State of the Art 3, 13 20.
22 Bernard V. Traynor, Jr., Electrodril Demonstration Program Shows Promise, MWD: State of the Art-3, 13-20.
23 * Chuck McCabe, MWD Innovations Could Sharply Reduce Drilling Costs , Ocean Industry, 38 40, Jun. 1984.
24 Chuck McCabe, MWD Innovations Could Sharply Reduce Drilling Costs, Ocean Industry, 38-40, Jun. 1984.
25 * Combining MWD Systems into a Single Package , The Oilman, 40,43, Nov. 1986.
26 Combining MWD Systems into a Single Package, The Oilman, 40,43, Nov. 1986.
27 * Cylindrical Laser Lithium Primary Batteries (Bobbin structure), Lithium Primary Batteries, pp. 11 12.
28 Cylindrical Laser Lithium Primary Batteries (Bobbin structure), Lithium Primary Batteries, pp. 11-12.
29 * D. R. Tanguy, et al., Applications of Measurements While Drilling , Society of Petroleum Engineers, of AIME, SPE 10324, 1981.
30 D. R. Tanguy, et al., Applications of Measurements While Drilling, Society of Petroleum Engineers, of AIME, SPE 10324, 1981.
31 * David G. Franz, Downhole Recording System for MWD , Society of Petroleum Engineers of AIME, SPE 10054, 1981.
32 David G. Franz, Downhole Recording System for MWD, Society of Petroleum Engineers of AIME, SPE 10054, 1981.
33 * Donald S. Grosso, et al., Report on MWD Experimental Downhole Sensors , Journal of Petroleum Technology, 899 904, May 1983.
34 Donald S. Grosso, et al., Report on MWD Experimental Downhole Sensors, Journal of Petroleum Technology, 899-904, May 1983.
35 * Du Pont PYRALUX Flexible Composites, Section II, Oct., 1986.
36 * Du Pont PYRALUX Flexible Composites, Section X, Oct., 1986.
37 * E. B. Denison, High Data Rate Drilling Telemetry System , Journal of Petroleum Technology, 155 163, Feb. 1979.
38 E. B. Denison, High Data-Rate Drilling Telemetry System, Journal of Petroleum Technology, 155-163, Feb. 1979.
39 * Elapsed Time Logging , The Oilman, 8, Nov. 1986.
40 Elapsed Time Logging, The Oilman, 8, Nov. 1986.
41 * F. W. Legros, Jr., Multisensor MWD System Successfully Used , Drilling Contractor, 32 34, Jun. 1985.
42 F. W. Legros, Jr., Multisensor MWD System Successfully Used, Drilling Contractor, 32-34, Jun. 1985.
43 * Gearhart Qwen uses Negative Pressure Pulse in MWD, MWD : State of the Art 7, 37 39.
44 Gearhart-Qwen uses Negative Pressure Pulse in MWD, MWD: State of the Art-7, 37-39.
45 * J. B. Cheatham Jr., Drilling Technology: Present Trends and Future Projects , Society of Petroleum Engineers of AIME, SPE 12358, 1983.
46 J. B. Cheatham Jr., Drilling Technology: Present Trends and Future Projects, Society of Petroleum Engineers of AIME, SPE 12358, 1983.
47 * J. L. Marsh, et al., Measurement While Drilling Mud Pulse Detection Process: An Investigation of Matched Filter Responses to Simulated and Real Mud Pressure Pulses , Society of Petroleum Engineers, SPE 17787, 1988.
48 J. L. Marsh, et al., Measurement-While-Drilling Mud Pulse Detection Process: An Investigation of Matched Filter Responses to Simulated and Real Mud Pressure Pulses, Society of Petroleum Engineers, SPE 17787, 1988.
49 * J. L. Thorogood, Discussion of MWD North Sea Field Use, Aug. 1978 Feb. 1979 (with 1982 Update) , Journal of Petroleum Technology, 905 907, May 1983.
50 J. L. Thorogood, Discussion of MWD North Sea Field Use, Aug. 1978-Feb. 1979 (with 1982 Update), Journal of Petroleum Technology, 905-907, May 1983.
51 * John E. Fontenot, et al., Measurement While Drilling Essential to Drilling , Technology, 52 58, Mar. 1988.
52 John E. Fontenot, et al., Measurement While-Drilling Essential to Drilling, Technology, 52-58, Mar. 1988.
53 * John E. Fontenot, Measurement While Drilling A New Tool , Journal of Petroleum Technology, 128 130, 1986.
54 * John E. Fontenot, Measurement While Drilling A New Tool , Journal of Petroleum Technology, 128 130, Feb. 1986.
55 John E. Fontenot, Measurement While Drilling--A New Tool, Journal of Petroleum Technology, 128-130, 1986.
56 John E. Fontenot, Measurement While Drilling--A New Tool, Journal of Petroleum Technology, 128-130, Feb. 1986.
57 * John E. Fontenot, The Place of Technology for Measurement While Drilling in the Ocean Margin Drilling Program, 11 16.
58 John E. Fontenot, The Place of Technology for Measurement While Drilling in the Ocean Margin Drilling Program, 11-16.
59 * John Pedigo, et al., An Acoustically Controlled Down Hole Safety Valve, (SCSSSV) , Society of Petroleum Engineers of AIME, SPE 6026, 1976.
60 John Pedigo, et al., An Acoustically Controlled Down-Hole Safety Valve, (SCSSSV), Society of Petroleum Engineers of AIME, SPE 6026, 1976.
61 * L. J. Field, et al., Automatic Bit Locator Uses Mud Pulse Telemetry for Wellbore Steering , Technology, 155 167, Apr. 1981.
62 L. J. Field, et al., Automatic Bit Locator Uses Mud Pulse Telemetry for Wellbore Steering, Technology, 155-167, Apr. 1981.
63 * L. R. Elliott, et al., Recording Downhole Formation Date While Drilling , Society of Petroleum Engineers of AIME, SPE 12360, 1983.
64 L. R. Elliott, et al., Recording Downhole Formation Date-While Drilling, Society of Petroleum Engineers of AIME, SPE 12360, 1983.
65 * M. Vikram Rao, et al., Many Factors Determine Need for Real time or Recorded Data , Technology, 65 69, Jan. 1988.
66 M. Vikram Rao, et al., Many Factors Determine Need for Real-time or Recorded Data, Technology, 65-69, Jan. 1988.
67 * Magnetic Particle Inspection , Non Destructive Testing, 18 31.
68 Magnetic Particle Inspection, Non-Destructive Testing, 18-31.
69 * Majors do Basic Research on MWD, MWD : State of the Art 9, 45 55.
70 Majors do Basic Research on MWD, MWD: State of the Art-9, 45-55.
71 * Marvin Gearhart, et al., Mud Pulse MWD Systems Report , Journal of Petroleum Technology, 2301 2306, Dec. 1981.
72 * Marvin Gearhart, et al., Mud Pulse MWD Systems Report , Journal of Petroleum Technology, Dec. 1981.
73 Marvin Gearhart, et al., Mud Pulse MWD Systems Report, Journal of Petroleum Technology, 2301-2306, Dec. 1981.
74 Marvin Gearhart, et al., Mud Pulse MWD Systems Report, Journal of Petroleum Technology, Dec. 1981.
75 * MWD Economics Still a Problem , Offshore, 66 67, Oct. 1984.
76 MWD Economics Still a Problem, Offshore, 66-67, Oct. 1984.
77 * MWD Update: New Systems Operating , Oil & Gas Journal, 126 148, Mar. 1980.
78 MWD Update: New Systems Operating, Oil & Gas Journal, 126-148, Mar. 1980.
79 * NL Uncovers Neutron MWD Tool , The Oilman, 36, Nov. 1986.
80 NL Uncovers Neutron MWD Tool, The Oilman, 36, Nov. 1986.
81 * Proceedings, Measurement While Drilling Symposium, Louisiana St. Univ. Baton Rouge, LA, 277 297, Feb. 1990.
82 Proceedings, Measurement While Drilling Symposium, Louisiana St. Univ. Baton Rouge, LA, 277-297, Feb. 1990.
83 * R. F. Spinner, et al., MWD Program Nearing Commerciality, MWD : State of the Art 4, 21 28.
84 R. F. Spinner, et al., MWD Program Nearing Commerciality, MWD: State of the Art-4, 21-28.
85 * R. L. Monti, et al., Optimized Drilling Closing the Loop , Twelfth World Petroleum Congress, vol. 3, 131 142, 1979.
86 R. L. Monti, et al., Optimized Drilling--Closing the Loop, Twelfth World Petroleum Congress, vol. 3, 131-142, 1979.
87 * Ralph F. Spinner, et al., MUD Pulse Telemetry System Used in Directional Drilling , prepared for the Department of Energy, 1 22.
88 Ralph F. Spinner, et al., MUD Pulse Telemetry System Used in Directional Drilling, prepared for the Department of Energy, 1-22.
89 * Robert Desbrandes, et al., MWD Transmission Data Rades Can be Optimized , Petroleum Engineer, 46 52, Jun. 1987.
90 Robert Desbrandes, et al., MWD Transmission Data Rades Can be Optimized, Petroleum Engineer, 46-52, Jun. 1987.
91 * Robert Newton, et al., A Case Study Comparison of Wells Drilled With and Without MWD Directional Surveys on the Claymore Platform in the North Sea , Journal of Petroleum Technology, 1867 1876, Nov. 1980.
92 Robert Newton, et al., A Case Study Comparison of Wells Drilled With and Without MWD Directional Surveys on the Claymore Platform in the North Sea, Journal of Petroleum Technology, 1867-1876, Nov. 1980.
93 * Robert O. Frederick, MWD A Tough Nut With a Bright Future , Drilling, Jul. 1980.
94 Robert O. Frederick, MWD A Tough Nut With a Bright Future, Drilling, Jul. 1980.
95 * S. J. Chen, et al., Numerical Simulation of MWD Pressure Pulse Transmission , Society of Petroleum Engineers, SPE 14324, 1985.
96 S. J. Chen, et al., Numerical Simulation of MWD Pressure Pulse Transmission, Society of Petroleum Engineers, SPE 14324, 1985.
97 * T. R. Bates, et al., Downhole Measurements While Drilling , Eleventh World Petroleum Congress, vol. 3, 25 33.
98 T. R. Bates, et al., Downhole Measurements While Drilling, Eleventh World Petroleum Congress, vol. 3, 25-33.
99 * Thomas R. Bates, Jr., et al., Multisensor Measurements While Drilling Tool Improves Drilling Economics , OJI Report, 119 137, Mar. 1984.
100 Thomas R. Bates, Jr., et al., Multisensor Measurements-While-Drilling Tool Improves Drilling Economics, OJI Report, 119-137, Mar. 1984.
101 * Thomas S. Matthews, Bidirectional Telemetry for Downhole Well Logging , Petroleum Engineer, 56 62, Sep.
102 Thomas S. Matthews, Bidirectional Telemetry for Downhole Well Logging, Petroleum Engineer, 56-62, Sep.
103 * Wanye Sullivan, Teleorienter Can Speed Directional Drilling , The Drilling Contractor, 32 35, Jan. Feb. 1974.
104 Wanye Sullivan, Teleorienter Can Speed Directional Drilling, The Drilling Contractor, 32-35, Jan.-Feb. 1974.
105 * Will Honeyborne, Formation MWD Benefits Evaluation and Efficiency , Technology, 83 92, Feb. 1985.
106 Will Honeyborne, Formation MWD Benefits Evaluation and Efficiency, Technology, 83-92, Feb. 1985.
107 * Will Honeyborne, Future Measurement While Drilling Technology Will Focus on Two Levels , OGJ Report, 71 75, Mar. 1985.
108 Will Honeyborne, Future Measurement-While-Drilling Technology Will Focus on Two Levels, OGJ Report, 71-75, Mar. 1985.
109 * William D. Squire, A New Approach to Drill String Acoustic Telemetry, Society of Petroleum Engineers of AIME, SPE 8340, 1979.
110 William D. Squire, A New Approach to Drill-String Acoustic Telemetry, Society of Petroleum Engineers of AIME, SPE 8340, 1979.
111 * William J. McDonald, et al., Logging While Drilling: A Survey of Methods and Priorities, SPWLA Seventeenth Annual Logging Symposium, 1 15, Jun. 1976.
112 William J. McDonald, et al., Logging While Drilling: A Survey of Methods and Priorities, SPWLA Seventeenth Annual Logging Symposium, 1-15, Jun. 1976.
113 * William J. McDonald, et al., MWD Will Broaden Offshore Horizons , Offshore, 87 91, Dec. 1977.
114 William J. McDonald, et al., MWD Will Broaden Offshore Horizons, Offshore, 87-91, Dec. 1977.
115 * William J. McDonald, Four Basic Systems Will be Offered , Offshore, 92 103, Dec. 1977.
116 William J. McDonald, Four Basic Systems Will be Offered, Offshore, 92-103, Dec. 1977.
117 * William J. McDonald, MWD Looks Best for Directional Work and Drilling Efficiency , Technology.
118 William J. McDonald, MWD Looks Best for Directional Work and Drilling Efficiency, Technology.
119 * Wilton Gravley, Review of Downhole Measurements While Drilling Systems , Society of Petroleum Engineers, SPE 10036, 1982.
120 Wilton Gravley, Review of Downhole Measurements-While Drilling Systems, Society of Petroleum Engineers, SPE 10036, 1982.
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U.S. Classification 166/373, 166/376, 166/66.7
International Classification E21B23/04, E21B34/06
Cooperative Classification E21B23/04, E21B34/066, E21B34/06
European Classification E21B34/06, E21B23/04, E21B34/06M
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