METHODS OF DRILLING A WELL HOLE

专利摘要:
method of drilling a well hole, actuator and bypass tool for use in a well hole. the present invention relates to a method of drilling a well hole which includes drilling a well hole through a formation by injecting drilling fluid (1045f) through a drilling column (1050), and turning a drill bit. the drill string (1050) includes a bypass tool (1050s), a receiver in communication with the bypass tool (1050s), and the drill. the method also includes retrieving the drilling column (1050) from the well hole (1005) through a sealing lining column (1015) until the bypass tool (1050s) reaches an actuator. the sealing liner (1015) includes an isolation valve (50) in an open position and the actuator. the method also includes sending a wireless instruction signal to the receiver. the bypass tool (1050s) encloses the actuator in response to the receiver, receiving the instruction signal. the method also includes operating the actuator using the deviation tool (1050s) fitted, thus closing the isolation valve (50) and isolating the formation of an upper portion of the well hole (1005). the present invention also relates to an actuator and a bypass tool (1050s) for use in a well bore.
公开号:BR112013008612B1
申请号:R112013008612-2
申请日:2011-09-20
公开日:2020-12-15
发明作者:Joe Noske；Roddie R. Smith；Paul L. Smith；Thomas F. Bailey；Christopher L. Mcdowell；Frederick T. Tilton
申请人:Weatherford/Lamb, Inc；
IPC主号:

专利说明:

CROSS REFERENCE FOR RELATED ORDERS
This application claims the benefit of US Provisional Patent Application Serial No. 61 / 384,493 filed on September 20, 2010 and US Provisional Patent Application Serial No. 13 / 227,847 filed on September 8, 2011. Both of these applications are incorporated herein as a reference in their entirety. BACKGROUND OF THE INVENTION Field of the Invention
The present invention relates, in general, to a signal operated isolation valve. Description of the Prior Art
A hydrocarbon-containing formation (ie, crude oil and / or natural gas) is accessed by drilling a well hole from an earth surface until the formation. After the well hole is drilled to a certain depth, a steel casing or seal liner is typically inserted into the well hole and an annular space between the casing / seal liner and the earth is filled with cement. The casing / sealing liner reinforces the uncoated bore, and the cement helps to isolate areas of the borehole during continued drilling and hydrocarbon production.
Once the borehole has reached formation, the formation will then normally be drilled in a condition of greater imbalance, which means that the pressure in the annular space exerted by the returns (drilling fluid and shavings) will be greater than the pressure of portion of the formation. Disadvantages of operating in the condition of major imbalance include the use of drilling mud and damage to formations caused by the entry of mud into the formation. Therefore, pressure drilling with minor or managed imbalance can be employed to avoid or at least mitigate drilling problems with major imbalance. In pressure drilling with minor and managed imbalance, a light drilling fluid, such as liquid or a gas-liquid mixture, is used instead of heavy drilling mud in order to prevent or at least reduce the entry of drilling fluid and the consequent damage to the formation. Since drilling with a smaller and managed imbalance is more susceptible to the occurrence of jets (formation fluid entering the annular space), well and lower-unbalanced well holes are drilled using a rotary control device (RCD) ( also known as rotary bypass, rotary BOP, rotary drill head, or PCWD). The RCD allows the drill string to be rotated and lowered through it, while maintaining a pressure seal around the drill string.
An isolation valve located inside the enclosure / sealing liner can be used to temporarily isolate a forming pressure below the isolation valve, so that a drill or work column can be quickly and safely inserted into a portion of the hole well above the isolation valve which is temporarily relieved to atmospheric pressure. An example of an isolation valve having a hinge is discussed and illustrated in US Patent 6,209,663 which is incorporated herein by reference in its entirety. An example of an isolation valve having a ball is discussed and illustrated in US Patent 7,204,315 which is incorporated herein by reference in its entirety. The isolation valve allows a drill / work column to be dragged in and out of the well bore at a speed greater than force on the column under low pressure. As the pressure above the isolation valve is reduced, the drill / work column can cause a maneuver into the well hole without the pressure of the well hole acting to push the column out. In addition, the isolation valve allows the drilling / work column to be inserted into the well bore which is incompatible with the hydraulic ram due to the shape, diameter and / or length of the column.
Drive systems for the isolation valve are typically hydraulic requiring one or two control lines that extend from the isolation valve to the surface. Control lines require protection against breakage, are susceptible to leakage, and would be difficult to guide through a subsequent wellhead. SUMMARY OF THE INVENTION
Modalities of the invention generally refer to a signal operated isolation valve. In one embodiment, a method of drilling a well hole includes drilling the well hole through a formation by injecting fluid through a drill string and turning a drill bit. The drill string includes a bypass tool, a receiver in communication with the bypass tool, and the drill bit. The method also includes recovering the drilling column from the well hole through a housing column until the bypass tool reaches an actuator. The housing column includes an isolation valve in an open position and the actuator. The method also includes sending an instructional signal to the receiver without using a wire. The bypass tool engages the actuator in response to receiving the instruction signal by the receiver. The method also includes operating the actuator using the fitted diverter tool, thus closing the isolation valve and isolating the formation of an upper portion of the well hole.
In another embodiment, a method of drilling a well hole includes drilling the well hole through a formation by injecting drilling fluid through a drilling column, and turning a drill bit and recovering the drilling column from the well hole through of a casing column until the drill bit is above a closing member. The housing column includes the closing member in an open position and an actuator. The method also includes sending a wireless instruction signal to the actuator, and closing the closing member, thereby isolating the formation of an upper portion of the well hole.
In another embodiment, an actuator for use in a well hole includes: a tubular housing having a hole formed through it; a source of energy; a receiver for receiving an instructional signal without using a wire; a controller communicating with the power source and the antenna; a pump or piston operable to supply pressurized hydraulic fluid to an isolation valve; a position or proximity sensor in communication with the controller to determine an isolation valve position; and a lock operationally connected to the pump or piston and the controller. The controller is operable to release the lock in response to receiving the instruction signal.
In another embodiment, a diversion tool for use in a well hole includes: a tubular housing having a hole formed through it and a pocket formed in its wall; an actuator movable in relation to the housing between an extended position and a retracted position and arranged in the bag in the retracted position; a piston disposed in the housing, longitudinally movable with respect to it between an engaged position and an undocked position, and operable to extend the actuator when moving from the disengaged position to the engaged position; an operable lock to retain the piston in the engaged position; and an operable actuator to release the lock in response to receiving an instruction signal. BRIEF DESCRIPTION OF THE FIGURES
In order that the manner in which the above-mentioned features of the present invention can be understood in detail, a more particular description of the invention, briefly summarized above, can be made with reference to the modalities, some of which are illustrated in the accompanying drawings. It should be noted, however, that the attached drawings illustrate only typical modalities of this invention and, therefore, should not be considered as limiting its scope, since the invention may admit other equally effective modalities.
Figures 1A-C are cross-sections of an insulation assembly in the closed position, according to an embodiment of the present invention.
Figure 2A is a cross-section of a deviation tool for driving the insulation assembly between the positions, according to another embodiment of the present invention. Figures 2B and 2C illustrate a telemetry sub for use with the bypass tool. Figure 2D is an enlargement of a portion of Figure 2A.
Figure 3 A illustrates a packaging of the electronic components of the telemetry sub. Figure 3B is an active RFID tag for use with the telemetry sub. Figure 3C illustrates a passive RFID tag for use with the telemetry sub. Figure 3D illustrates an RFID tag with Platform for Wireless Identification and Capture (WISP) for use with the telemetry sub. Figure 3E illustrates accelerometers in the telemetry sub. Figure 3F illustrates a mud pulser from the telemetry sub.
Figure 4A illustrates a sub power for use with the insulation assembly, according to another embodiment of the present invention. Figures 4B-4E illustrate the operation of the sub power.
Figure 5 illustrates a position indicator for the isolation valve, according to another embodiment of the present invention.
Figures 6A and 6B illustrate an isolation valve in the closed position, according to another embodiment of the present invention. Figure 6C is an enlargement of a portion of Figure 6A.
Figure 7A illustrates another way of operating the isolation valve, according to another embodiment of the present invention. Figure 7B illustrates a charger for use with an isolation valve, according to another embodiment of the present invention. Figure 7C is an isometric view of the charger in Figure 7B. Figure 7D illustrates another charger for use with an isolation valve, in accordance with another embodiment of the present invention. Figure 7E illustrates another charger for use with an isolation valve, according to another embodiment of the present invention. Figure 7F is an enlargement of the charger. Figure 7G is a cross section showing two layers of the magazine.
Figures 8A-C illustrate another insulation assembly in the closed position, according to another embodiment of the present invention.
Figures 9A-C illustrate another insulation assembly in the closed position, according to another embodiment of the present invention. Figures 9D-9E illustrate the operation of an actuator in the insulation assembly.
Figures 10A and 10B illustrate a portion of another isolation valve in the open and closed positions, respectively, according to another embodiment of the present invention.
Figure 11A illustrates a drilling rig for drilling a well hole, according to another embodiment of the present invention. Figures 11B-11I illustrate a method of drilling and completing a well hole using the drilling rig.
Figure 12A illustrates a portion of a power sub for use with the insulation assembly in a stowed position, according to another embodiment of the present invention. Figure 12B illustrates a portion of the power sub in an extended position.
Figure 13A is a cross-section of a deviation tool for driving the insulation assembly between the positions, according to another embodiment of the present invention. Figures 13 B and 13C illustrate a portion of an isolation valve in the closed position, according to another embodiment of the present invention. DETAILED DESCRIPTION OF THE PREFERRED MODE
Figures 1A-C are cross-sections of an insulation assembly in the closed position, according to another embodiment of the present invention. The insulation assembly may include one or more power subs 1, a spacer sub 25, and the isolation valve 50. The insulation assembly may be assembled as part of a 1015 enclosure or sealing liner and operate within a well bore 1005 (see Figure 11B). The casing 1015 or seal liner column can be cemented (a) into well bore 1005 or be a connector casing column. Although only one energy sub 500 is shown, two subs can be used in a tripartite configuration, discussed below.
The power sub 1 may include a tubular housing 5 and a tubular mandrel 10. The housing 5 may have couplings (not shown) formed at each longitudinal end thereof for connection with other components of the housing / casing column. Couplings can be threaded, such as a box and a pin. The housing 5 can have a central longitudinal hole formed through it. Although shown in one piece, housing 5 may include two or more sections to facilitate fabrication and assembly, each section connected together, for example, secured with threaded connections.
The mandrel 10 can be arranged within the housing 5 and longitudinally movable with respect to it. The mandrel 10 can have a profile 10p formed on an internal surface of it to receive a strut 130 from a deflection tool 100. Mandrel 10 can also have one or more position indicators 15p, l embedded in an internal surface. of it and the housing 5 may have one or more position indicators 15h embedded (s) in an internal surface of the same. Alternatively, the indicator 15h can in turn be embedded in an internal surface of the spacer housing 30. The mandrel 10 may also have a projection 10s for piston formed on an external surface of the same or attached to it. The projection 10s for the piston can be arranged in a chamber 6. The housing 5 can also have projections upper 5u and lower 51 formed on an internal surface of the same. The chamber 6 can be defined radially between the mandrel 10 and the housing 5 and longitudinally between an upper seal arranged between the housing 5 and the mandrel 10 near the upper projection 5u and a lower seal disposed between the housing 5 and the mandrel 10 near the bottom projection 51. Hydraulic fluid can be arranged in chamber 6. Each end of chamber 6 can be in fluid communication with a respective hydraulic coupling 9c via a respective hydraulic passage 9p formed longitudinally through a wall of the housing 5.
The spacer sub 25 can include a tubular housing 30 having couplings (not shown) formed at each of its longitudinal ends for connection to the power sub 1 and the isolation valve 50. The couplings can be threaded, such as with a pin and a box. The spacer sub 25 may further include hydraulic ducts, such as production tubes 29t, attached to an external surface of the housing 30 and hydraulic couplings 29c connected to each end of the production tubes 29t. Hydraulic couplings 29c can pair with respective hydraulic couplings of power sub 1 and isolation valve 50. Spacer sub 25 can provide fluid communication between a passage 9b for the power sub and a respective passage 59p for the isolation valve. The spacer sub 25 may also be of sufficient length to accommodate the BHA of the drill string while the bypass tool 100 is engaged with the power sub 1, thus providing a longitudinal clearance between the drill bit and a valve hinge 70 The length of the spacer sub may depend on the length of the BHA.
The isolation valve 50 can include a tubular housing 55, a flow tube 60, and a closing member, such as valve hinge 70. As discussed above, the closing member can be a ball (not shown) instead hinge 70. To facilitate manufacturing and assembly, housing 55 may include one or more sections 55a, b, each connected to one another, secured, for example, with connections and / or threaded fasteners. Housing 55 may further include an upper adapter (not shown) connected to section 55a for connection to the spacer sub 25 and a lower adapter (not shown) connected to section 55b for connection to the housing or liner. The housing 55 may have a longitudinal hole formed through it for the passage of a drill string.
The flow tube 60 can be arranged inside the housing 55. The flow tube 60 can be movable in the longitudinal direction with respect to the housing 55. A piston 61 can be formed on the outer surface of the flow tube 60 or attached thereto. Piston 61 may include one or more seals to fit an inner surface of a chamber 57 formed in housing 55 and one or more seals to fit an outer surface of flow tube 60. Housing 55 may have projections upper 55u and lower 551 formed on an internal surface thereof. The chamber 57 can be defined radially between the flow tube 60 and the housing 55 and longitudinally between an upper seal disposed between the housing 55 and the flow tube 60 near the projection 55u and a lower seal disposed between the housing 55 and the tube flow rate close to the lower projection 551. Hydraulic fluid can be disposed in chamber 57. Each end of chamber 57 can be in fluid communication with a respective hydraulic coupling 59c via a respective hydraulic passage 59p formed through a wall of housing 55.
The flow tube 60 can be moved in the longitudinal direction by the piston 61 between the open position and the closed position. In the closed position, the flow tube 60 can move away from the hinge 70, thus allowing the hinge 70 to close. In the open position, the flow tube 60 can fit in the hinge 70, push the hinge 70 into the open position, and fit in a seat 58s formed in the housing 55. The fit of the flow tube 60 with the seat 58s can form a chamber 56 between the flow tube 60 and the housing 55, thus protecting the hinge 70 and the seat 56s of the hinge. The hinge 70 can be articulated with the housing 55, by means of, for example, a fastener 70p. A tensioning member, such as a torsion spring (not shown), can fit into hinge 70 and housing 55 and be arranged around fastener 70p to tension hinge 70 in the direction of the closed position. In the closed position, the hinge 70 can fluidly isolate an upper portion of the valve from a lower portion of the valve.
Figure 2A is a cross-section of a deviation tool 100 to drive the insulation assembly between the positions, according to another embodiment of the present invention. Figure 2D is an enlargement of Figure 2A. The bypass tool 100 may include a tubular housing 105, a tubular piston 110, and one or more longitudinal actuators, such as struts 130, and an actuator, such as a hydraulic lock 150. Housing 105 may have couplings 107b, p formed at each of its longitudinal ends for connection with other components of a drill string. Couplings can be threaded, such as a box 107b and a pin 107p. Housing 105 may have a central longitudinal hole formed therethrough to conduct the drilling fluid. Housing 105 may include one or more sections (only one section is illustrated) to facilitate fabrication and assembly, each section being connected together, secured, for example, with threaded connections. An internal surface of the housing 105 may have a projection 105u and a lower projection 1051 formed therein.
The piston 110 can be disposed within the housing 105 and longitudinally movable with respect to it between a recessed position (shown) and an engaged position. The piston 110 may have a top 110t, one or more profiles, such as slits 110s, formed on an external surface thereof, one or more handles 110g formed on an external surface thereof, and a projection 1101 formed on an external surface of the same same. One or more fasteners, such as pins 118, can be arranged through respective holes formed through a wall of the housing and extend into the respective slots 110s, thus rotatingly connecting piston 110 to housing 105. In the recessed position, the top of the piston 110t can be stopped by being attached to a fastener, such as a ring 117, connected to the housing 105, by means of, for example, a threaded connection. The stop ring 117 can fit into the projection 105u of the upper housing. The top of the 105t piston may have a larger area than the bottom of the piston.
One or more reinforcements 105r can be formed on an external surface of the housing 105 and spaced around it. A pocket 105p can be formed through each reinforcement 105r. Strut 130 may be arranged in pocket 105p in the rearward position. The strut 130 can be moved outwardly towards the engaged position by one or more thrusters, such as wedges 115, arranged in pocket 105p. Each wedge 115 can include an inner serrated 115i and an outer serrated 115o. The internal serrated 115i can be connected to the handle 110g of the piston, using, for example, a fastener 116i. The outer serrated 115o can be connected to the strut 130, by means of, for example, a fastener 116o. A gap can be provided between the strut 130 and the outer serration 115o and / or the clamp 116o and a tensioning member, such as a Bellville spring 131, can be arranged between the outer serrated 115o and the strut 130 to tension the strut 130 until it fits with the fastener 116o. A seal can be arranged between the strut 130 and the housing 105.
An upper chamber may be defined radially between piston 110 and housing 105 and may include pocket 105p. The upper chamber can be defined longitudinally between one or more seals arranged between housing 105 and piston 110 near the upper part 110t of piston and one or more intermediate seals arranged between housing 105 and piston 110 near the lower projection 1101. Fluid hydraulic may be arranged in the upper chamber. A compensating piston 160 can be arranged in a passage 159v formed through a wall of the housing 105. A lower face of the compensating piston 160 can be in fluid communication with the exterior of the bypass tool 100 (that is, the annular space 1025 (Figure 11c), when arranged in well hole 1005) and an upper face of the compensating piston may be in fluid communication with the upper chamber. The compensating piston 160 can serve to equalize the pressure of the hydraulic fluid and account for changes in volume of the upper chamber due to the temperature and / or movement of the strut 130. A tensioning member, such as a helical spring 140, can be arranged to against the lower projections 1101, 1051, thus tensioning piston 110 in the direction of the stowed position. The helical spring 140 can be arranged in a lower chamber longitudinally defined between the intermediate seals and an intermediate seal arranged between the housing 105 and the piston 110 near the projection of the lower housing 1051 and radially between the piston 110 and the housing 105. The fluid hydraulic valve can be arranged in the lower chamber.
The hydraulic lock 150 may include one or more passages 159c, o formed through a wall of the housing 105 and one or more valves 152, 154 interconnected with the respective passages 159c, o. The hydraulic lock 150 can provide selective fluid communication between the upper and lower chambers. Valve 154 can be an operable check valve to allow fluid flow from the upper chamber to the lower chamber and prevent fluid flow from the lower chamber to the upper chamber. Valve 152 can be a control valve, such as a solenoid operated shut-off valve, operable between an open position and a closed position. Shut-off valve 152 can prevent flow in both directions between chambers in the open position. The solenoid can be tilted in the direction of the closed position. Lead wires 155 can extend from control valve 152 to pin 107p. An electrical coupling 107c can be arranged on pin 107p to receive electricity from telemetry sub 200. Coupling 107c can be made of inductive or contact rings.
Alternatively, the control valve 152 can be a solenoid operated check valve and the check valve 154 and the corresponding passage 159c can be omitted. The solenoid operated check valve can operate as a check valve in the closed position and allow bidirectional flow in the open position. Alternatively, actuator 150 can be an electromechanical lock (see actuator 750, discussed above).
Figures 2B and 2C illustrate a telemetry sub 200 for use with the bypass tool 100. The telemetry sub 200 can include a top adapter 205a, one or more auxiliary sensors 202a, b, a pressure sensor 204, a housing for downlink 205b, a sensor housing 205c, a pressure sensor 204, a downlink mandrel 210, an uplink housing 205d, a bottom adapter 205e, one or more electrical couplings 209a- e, a packaging for the components electronics 225, a battery 231, one or more antennas 226i, o, a tachometer 255, and a mud pulser 275. Each of the 205b-d housings can be modular, so that any of the 205b-d housings can be omitted and the remaining accommodations can be used together without modifying them. Alternatively, any of the sensors or electronic devices in the telemetry sub 200 can be incorporated into the bypass tool 100 and the sub detelemetry 200 can be omitted.
Each of the adapters 205a, and can be tubular and have a threaded coupling, such as a pin 207p and a box 207b, formed at a longitudinal end thereof for connection with the bypass tool 100 and another component of the drill string. Electrical coupling 209a can be arranged in box 207b to transmit electricity to control valve 152. Couplings 209a-e can be inductive or contact rings. Alternatively, a wet or dry pin connection and plug can be used to connect the telemetry sub 200 and bypass tool 100 instead of pin and box. Conductor wires 208 can connect couplings 209a, b and other components to electrical couplings. Each 205a-e housing can be longitudinally and rotatorily connected to the other by one or more fasteners, such as screws (not shown), and sealed by one or more seals, such as o-rings (not shown).
The sensor housing 205 can accommodate the pressure sensor 204 and the tachometer 255. The pressure sensor 204 can be in fluid communication with a hole in the sensor housing 205c via a first port and in fluid communication with the annular space over a second door. In addition, pressure sensor 204 can also measure the temperature of the drilling fluid and / or returns. The sensors 204,255 can be found in data communication with the electronic components package 225 by fitting the contacts 207c arranged on the top of the mandrel 210 with corresponding contacts 207c arranged on the bottom of the downlink housing 205b. Sensors 204, 255 can also receive electricity from the contacts. The sensor housing 205c can also relay data between the mud pulsator 275, auxiliary sensors 202, and the electronics package 225 via conduits 208 and radial contacts 209d, e. Auxiliary sensors 202 can be magnetometers that can be used with the tachometer 255 to determine direction information during drilling, such as azimuth, inclination, and / or tool face / inclined sub-angle. Each 226i antenna can include a inner line, a coil and an outer jacket arranged along an inner surface of the downlink mandrel 210 of the downlink housing 205b. The sealing coating can be made of a non-magnetic and non-conductive material, such as a polymer or compound, having an orifice formed longitudinally through it, and having a helical groove formed on an external surface thereof. The coil can be wound around the helical groove and made of an electrically conductive material, such as a metal or an alloy. The outer jacket can be made from non-magnetic and non-conductive material and can isolate the downlink mandrel coil 210 or downlink housing 205b. Antennas 226i, o can be connected longitudinally and rotatively to the downlink chuck 206 and without communication with a hole in the telemetry sub 200.
Figure 3A illustrates the packaging of electronic components 225. Figure 3B illustrates an RFID tag 250a for use with the telemetry sub 200. Figure 3C illustrates an RFID tag 250p for use with the telemetry sub 200. Figure 3D illustrates a platform for identification and capture without using a wire (WISP) RFID 250w for use with the telemetry sub 200. The packaging of the electronic components 225 can communicate with any of the RFID tags 250a, p, w. Any of the RFID tags 250a, p, w can be individually closed and thrown or pumped through the drill string. The packaging of electronic components 225 can be in electrical communication with antennas 226i, o and receive electricity from battery 231. The packaging of electronic components 225 can include an amplifier 227, a filter and detector 228, a transceiver 229, a microprocessor 230, a RF switch 234, pressure switch 233, and RF field generator 232. Alternatively, the tags 250a, p, w and electronics packaging 225 can operate at any other frequency without using a wire, such as acoustics.
The pressure switch 233 can remain open on the surface to prevent the packaging of electronic components 225 from becoming an ignition source. Once the telemetry sub 200 is implanted to a sufficient depth in the well bore, the pressure switch 233 can close. The microprocessor 230 can also detect implantation in the well hole using the pressure sensor 205. The microprocessor 230 can delay the activation of the transmitter for a predetermined period of time ** to conserve battery 231.
When it is desired to operate the bypass tool 100, one of the tags 250a, p, w can be pumped or dropped from the drilling probe 1000 (Figure 11A) to the antenna 226i. If a passive 250p or WISP tag is implanted, microprocessor 230 can begin transmitting a signal and listening for a response. Since tag 250p, w is implanted in the vicinity of antenna 26i, tag 250p, w can receive the signal, convert the signal to electricity, and transmit a response signal. The 226i antenna can amplify, filter, demodulate, and analyze the signal. If the signal equals a predetermined instruction signal, then microprocessor 230 can operate control valve 152 by supplying electricity to it. The instruction signal carried by the tag 250a, p, w can include a command, so as to extend or retract the strut 130. If an active tag 250a is used, then tag 250a can include its own battery, pressure switch, and timer, so that tag 250 a can perform the function of components 232-234.
The WISP 250w label can include a date and time stamp so that multiple labels can be pumped for repetition. In this way, if any of the labels get stuck in the well hole and later dislodged, the microprocessor 230 can disregard the command if it has already received the command with the same seal or another one with a later date and time.
Figure 3E is a schematic cross-sectional view of the sensor module. The tachometer 255 may include two accelerometers of a diametrically opposed geometric axis 255a, b. The 255a, b accelerometers can be piezoelectric, magnetostrictive, servo-controlled, inverse pendulum or microelectromechanical (MEMS). The accelerometers 255a, b can be radially oriented on the X axis to measure the centrifugal acceleration Ac due to the rotation of the telemetry sub 200 to determine the angular velocity. The second accelerometer can be used to explain gravity G if telemetry sub 200 is used in a winding or horizontal well hole. Alternatively, accelerometers 255a, b can be tangentially oriented on the Y axis, have a double geometric axis, and / or asymmetrically arranged (regardless of the diameter and / or each accelerometer in a different radial location). In addition, accelerometers 255a, b can be used to calculate the inclination of the borehole and the face of the gravity tool during drilling. In addition, the sensor module may include a Z-axis longitudinal accelerometer. Alternatively, magnetometers can be used instead of accelerometers to determine angular velocity.
Instead of using one of the RFID tags 250a, p, w to drive the bypass tool 100, an instruction signal can be sent to controller 230 by modulating the angular speed of the drill string according to a predetermined protocol. The modulated angular speed can be detected by the tachometer 255. The microprocessor 230 can then demodulate the signal and operate the bypass tool 100. The protocol can represent data by varying the existing angular speed to off, a lower speed for a higher speed and / either a higher speed for a lower speed, or monotonically increasing from a lower speed to a higher speed and / or a higher speed for a lower speed.
Figure 3F illustrates mud pulsator 275. Mud pulsator 275 can include a valve, such as a head 276, a driver 277, a turbine 278, a generator 279, and a seat 280. Head 276 can be moved longitudinally by actuator 277 relative to seat 280 between an open position (shown) and a drowned position (dotted) to selectively restrict the flow through pulsator 275, thereby creating pressure pulses in the pressure fluid pumped through the mud sweeper.
Mud pulses can be detected on the surface, thus communicating data from microprocessor 230 to the surface. The turbine 278 can use the fluid energy of the drilling fluid pumped through it and rotate the generator 279, thus producing electricity to energize the mud pulsator 275. The mud pulser 275 can be used to send confirmation of receipt of commands and report the successful execution of commands or errors to the surface. Confirmation can be sent during the drilling fluid circulation. Alternatively, a negative or sinusoidal mud pulsator can be used instead of the positive mud pulsator 275. Microprocessor 230 can also use turbine 278 and / or pressure sensor 204 as a flow switch and / or a flow meter .
Instead of using one of the RFID tags 250a, p, w or angular speed modulation to activate bypass tool 100, a signal can be sent to microprocessor 230 by modulating a flow rate of the probe's drilling fluid pump according to a predetermined protocol. Alternatively, a mud pulsator (not shown) can be installed at the outlet of the probe pump and operated by a 1070 surface controller (Figure 11A) to send pressure pulses from the drilling rig 1000 to the telemetry sub microprocessor 230 according to a predetermined protocol. The microprocessor 230 can use the turbine and / or the pressure sensor as a flow switch and / or flow meter to detect the sequencing of the burst pumps / pressure pulses. The flow rate protocol can represent data by varying the existing flow rate from on to off, a lower speed to a higher speed and / or a higher speed to a lower speed, or monotonically increasing from a faster speed low to a higher speed and / or from a higher speed to a lower speed. Alternatively, a commutator or orifice flow meter can be used to receive pressure pulse / flow rate signals communicated through the drilling fluid of probe 1000 instead of turbine 278 and / or pressure sensor 204. Al- 18/65 ternatively, the sensor sub can detect pressure pulse / flow rate signals using pressure sensor 204 and accelerometers 255a, b to monitor for BHA vibration caused by the pressure pulse signal / flow rate.
Alternatively, an electromagnetic slack (EM) sub (not shown) can be used instead of the mud pulser 275, thus allowing data to be transmitted to the microprocessor and / or to the surface using electromagnetic waves. Alternatively, a transverse EM antenna can be used instead of the EM slack sub. Alternatively, an RFID tag launcher (not shown) can be used instead of the mud pulsator. The tag launcher can include one or more 250w RFID tags. The microprocessor 230 can then encode the labels with data and the label launcher can release the labels onto the surface. Alternatively, an acoustic transmitter can be used instead of the mud thruster. For deeper wells, the drill string may also include a signal repeater (not shown) to prevent attenuation of the transmitted mud pulse. The repeater can detect the mud pulse transmitted from the mud pusher 475 and include its own mud pulser to repeat the signal. As many repeaters can be arranged along the working column as needed to transmit the data to the surface, for example, one repeater every five thousand feet. The repeaters can be used for any of the mud pulsator alternatives discussed above. Repeating the transmission can increase the bandwidth for specific data transmission. Alternatively, the telemetry sub can send and receive instructions via a wired drill string.
In operation, the bypass tool 100 and the telemetry sub 200 can be mounted as part of drill column 1050. Drill column 1050 can be inserted into well hole 1005 and microprocessor 230 can start transmitting a signal to seek by the 15p indicator. If, on the other hand, valve 50 is being closed after drilling, microprocessor 230 may be looking for indicator 15h to indicate proximity to profile 10p. The indicators 15p, l, h can each be an RFID tag, such as a passive 250p tag. Indicator 15p can operate to respond with a signal indicating the location on the profile and indicator 151 can be located to correspond to the external antenna when the strut 130 is attached to the profile. Since the external antenna 226o is in the range of indicator 15p, indicator 15p can respond, thus informing microprocessor 230 of the proximity of the 10p profile. The microprocessor 230 can send a signal to the probe 100, using, for example, the mud pulsator 275. The microprocessor 230 can send a signal to the probe 1000, using, for example, the mud pulsator 275. The bypass tool 100 can continue to be lowered until the microprocessor 230 detects the lower indicator 151 and sends a signal to the probe 1000 indicating the alignment of the strut 130 with the profile 10p.
An instruction signal can then be sent to the telemetry sub 200 by any of the ways discussed above, such as by pumping the RFID tag 250p through the drill string 1050 or by modulating the drill string rotation. Once the signal is sent, the drilling fluid can be pumped / continued to be pumped through the drill string, thus creating a pressure differential between the pressure in the drill string 1050 and the pressure in the annular space 1025 due to loss pressure through the drill bit 1050b. This pressure differential can exert a net downward force on piston 110 of the bypass tool which can be hydraulically closed by the closed control valve 152.
Once the telemetry sub 200 receives the signal and opens the control valve 152, the net pressure force can drive the piston 110 longitudinally downward and move the internal serrations 115i with respect to the external serrations 115o. Fasteners 116 o can be worn outside relative longitudinal movement of serrations 115i, o. Fasteners 116o can push the strut 130 to fit with the 10p sub-force profile. The fitting of the anchor 130 with the profile 10p can longitudinally connect the deflection tool 100 and the chuck of the sub-force 10. The longitudinal connection can be bidirectional or unidirectional. The bypass tool 100 can be lowered (or the lowering can continue), thus also moving the mandrel of the sub-force 10 longitudinally downwards and acting on the isolation valve 50. If only a sub-force is used (bidirectional connection) , then the bypass tool 100 can be raised or lowered depending on the last position of the isolation valve 50. The use of two subs of force 1 in the tripartite configuration in conjunction with the unidirectional (downward) connection beneficially allows the recovery of the drilling in the event of an emergency or other malfunction of the power subs 1 and / or bypass tool 100 simply by pulling up on the 1050 drill string.
The activation of sub-force 1 can be verified by the new detection of indicator 151. If the strut 130 did not fit in the profile 10p, then the detection of indicator 151 may not occur because the indicator is out of range or the microprocessor 230 may detect that the indicator is further away than it should be. Once the performance has been verified, the microprocessor 230 can report to the surface. The probe 1000 can then send an instruction signal to the microprocessor to retract the strut 130. The microprocessor can then close the control valve 152 and the circulation stopped, thus allowing the strut to retract.
Alternatively, a second instruction signal can be sent to the telemetry sub via a second wireless medium and the microprocessor 230 may not operate the bypass tool until 100 receive both instruction signals. Alternatively, the microprocessor can be programmed to autonomously extend the struts in response to the detection of the appropriate indicator (s) 15p, l, he / or autonomously retract the struts in response to the detection of the indicator (s) ) appropriate. Alternatively or in addition, the energy sub 1 can further include one or more latches, such as clamps or claws, disposed between the housing and the mandrel. The latch can provide resistance to the initial movement of the mandrel with respect to the detectable housing on the surface and avoid unintentional actuation due to accidental contact with other components of the drill string.
Figure 4A illustrates a sub-force 300 for use with the insulation assembly, according to another embodiment of the present invention. The sub-force 300 may include a tubular housing 305, a tubular mandrel 310, a piston 315, a tubular actuator 325, one or more indicators 340a-c, u, h and a clutch 350. Housing 305 may have couplings (not shown) ) formed at each of its longitudinal ends for connection with the spacer sub 25, and other components of the enclosure / cladding column. Couplings can be threaded, such as a box and a pin. The housing 305 can have a longitudinal perforation formed through it. Although shown as one piece, housing 305 can include two or more sections to facilitate fabrication and assembly, each section connected to the other, by means of, for example, threaded fastening connections.
The mandrel 310 can be arranged inside the housing 305, longitudinally connected to it, and can be rotated in relation to it. The strut 130 of the deflection tool 100 can be replaced by a rotary driver (not shown) and the mandrel 310 can have a profile 310p formed on an internal surface of the same to receive the driver. The profile can be a series of slits 310p spaced around the inner mandrel surface. Slots 310p may be longer than or substantially longer than the length of the bypass tool driver to provide a fit tolerance and / or compensate for lifting the 1050 drill string for subsea drilling operations. The mandrel 310 may also have one or more helical profiles 310t formed on an external surface thereof. If the chuck 310 has two or more helical profiles 310t (two illustrated), then the helical profiles can be interlaced.
The piston 315 can be tubular and have a projection 315s arranged in a lower chamber 306 formed in the housing 305. The housing 305 can also have projections upper 306u and lower 3061 formed on an internal surface thereof. The lower chamber 306 can be defined radially between piston 315 and housing 305 and longitudinally between an upper seal (not shown) disposed between housing 305 and piston 315 near the lower projection 3061. A piston seal (not shown) also it can be arranged between the piston projection 315s and the housing 305. The hydraulic fluid can be arranged in the lower chamber 306. Each end of the chamber 306 can be in fluid communication with a respective hydraulic coupling (not shown) via a respective hydraulic passage 309p formed longitudinally through a wall of housing 305.
Two energy subs 300 can be hydraulically connected to the isolation valve 50 in a three-way configuration, so that each of the pistons in the energy sub 315 is in opposite positions and the operation of one of the energy subs 300 will operate the valve. insulation 50 between the open and closed positions and switch the other energy sub 300. This tripartite configuration can allow each energy sub 300 to be operated in only one direction of rotation and that each energy sub 300 only opens or closes the control valve. insulation 50. The respective hydraulic couplings of each sub-power 300 and the isolation valve 50 can be connected by a conduit, such as production pipes (not shown).
Figures 4B-4E illustrate the operation of the power sub 300. The helical profiles 310t and the clutch 350 can allow the driver 325 to print a translation movement while it is not rotating, while the mandrel 310 is rotated by the power tool. deviation and does not receive the translation movement. Clutch 350 may include a tubular cam 335 and one or more followers 330. Cam 335 may be arranged in an upper chamber 307 formed in housing 305. Housing 305 may also have projections upper 307u and lower 3071 formed on an internal surface of the same. Chamber 307 can be defined radially between mandrel 310 and housing 305 and longitudinally between an upper seal disposed between housing 305 and mandrel 310 near the upper projection 307u and lower seals arranged between housing 305 and driver 325 and between the chuck 310 and driver 325 near the bottom projection 3071. Lubricant may be disposed in the chamber. A compensating piston (not shown) can be arranged in the chuck 310 or in the housing 305 to compensate for the displacement of the lubricant due to the movement of the driver 325. The compensating piston can also serve to equalize the pressure of the lubricant (or increase slightly) with pressure in the drilling the housing.
Each follower 330 can include a head 331, a base 333, and a tensioning member, such as a helical spring 332, arranged between the head 331 and the base 333. Each follower 330 can be arranged in a hole 325h formed through a driver wall 325. Follower 330 can be moved along a track 335t of cam 335 between an engaged position (Figures 4B and 4C), an undocked position (Figure 4E), and a neutral position (Figure 4D). The follower base 333 can fit in a respective helical profile 310t in the engaged position, thus operationally coupling the mandrel 310 and the driver 325. The head 331 can be connected to the base 333 in the engaged position by a pedestal. The 333 base may have a stop (not shown) to fit the pedestal in order to avoid separation.
Cam 335 can be longitudinally and rotatably connected to housing 305, using, for example, a threaded connection (not shown). Cam 335 can have one or more tracks 335t formed on it. When the driver 325 is moving down Md with respect to the housing 305 and the mandrel 310 (from the top position of the piston), each track 335t can be operable to push and hold down an upper part of the respective head 331, keeping it the base 333 fitted with the helical profile 310t and when the driver 325 is moving up Mu with respect to the housing 305 and the chuck 310, each track 335t can be operable to pull and hold a head edge 331 up, thus maintaining the base 333 detached from the helical profile 310t.
The driver 325 can be arranged between mandrel 310 and cam 335, rotatably connected to cam 335, and longitudinally movable with respect to housing 305 between an extended position (Figures 4A and 4D) and a recessed position (Figures 4B). A bottom part of driver 325 can make contact with a top of piston 315, thus pushing piston 315 from an upper position (Figure 4A) to a lower position when moving from the recessed positions to the extended positions. When the follower base 33 is engaged with the helical profile 310t (Figures 4B, 4C), the rotation of the mandrel 310 by fitting with the deflection tool can cause longitudinal downward movement of the driver relative to the housing, thus pushing the piston 315 to the bottom position. This conversion from rotary movement to longitudinal movement can be caused by a relative helical movement between the base of the follower 333 and the helical profile 310t.
Once the follower 330 reaches the bottom of the helical profile 310t and the end of the runway, the spring of the follower 332 can push the head 331 towards the neutral position since the continuous rotation of the mandrel 310 can push the base of the follower 333 for a groove 310g formed around an external surface of the mandrel 310, thus disengaging the base 333 of the follower of the helical profile 310t. Follower 330 may float radially in the neutral position so that the base 333 may or may not fit into slot 310g and / or remain in slot 310g. The groove 310g can ensure that the chuck 310 is free to rotate with respect to the driver 325 so that the continuous rotation of the chuck 310 does not damage either the bypass tool, the power sub 300, and the isolation valve 50.
Since the sub power is operated by the bypass tool, fluid force can push piston 315 in the direction of the upper position, thus pushing driver 325 longitudinally. Driver 325 can carry the follower along track 335t until the follower's head 331 engages the track 335t. As discussed above, the track 335t can engage the edge of the head and keep the base 33 detached from the helical profile 310t, so that the chuck 310 does not rotate back while the driver 325 moves longitudinally upwards with respect thereto. Once the follower 330 reaches the top of the second portion of the longitudinal track, the head of the follower 331 can engage an inclined portion of the track 335t where the follower 330 is compressed until the base 333 engages the helical profile 310t.
Each of the 340a-c, u, h indicators can be a 250p passive RFID tag. Indicators 340u, h can perform a function similar to indicators 15p, h and indicators 340a-c can perform a function similar to indicator 151. Indicator 340c can indicate piston movement 315 while indicators 340a, b can be used to compensate by lifting the drill string (discussed above). Indicators 340a-c, u, l can also include a tool address to distinguish between the opening and closing sub-force of the tripartite configuration discussed above.
Alternatively, the microprocessor can be programmed to autonomously extend the drivers in response to the detection of the appropriate indicator (s) 340a-c, u, he / or autonomously retract the drivers in response to the detection of the indicator (s) ( appropriate). Alternatively, or in addition, the energy sub 300 may further include one or more latches, such as clamps or claws, arranged between the piston and the housing. The latch can offer resistance to the initial movement of the piston in relation to the detectable housing on the surface and avoid unintentional actuation of the energy sub due to accidental contact with other components of the drilling column.
Figure 5 illustrates one or more position indicators 450o, c for an isolation valve, according to another embodiment of the present invention. The isolation valve 400 can be similar to the isolation valve 50 and include a housing 405, a flow tube 410, a hinge 420, and a hinge joint 420p.With respect to the isolation valve 50, an open indicator 450o and a closed indicator 450c has been added and flow tube 410 has been modified. Instead of fitting the hinge 420, the flow tube 410 can be connected to the hinge by a connection 413 attached to a lower end of the flow tube and the hinge, by means of, for example, articulation. As the flow tube 410 is moved longitudinally by the piston (not shown, see piston 61), connection 413 can push or pull the hinge, thus rotating the hinge to the open or closed position. The hinge spring can be omitted.
Each indicator 450o, c may include a chamber 451, a lever 455, a stem 456, one or more tensioning members, such as a coil spring 457 and a coil spring 458, a valve, such as a ball 459 , and a piston, such as a 460 disk. One or more RFID tags, such as passive 250p tags, may be arranged in chamber 451 and written on it (s) that the hinge is open. The chamber 451 can be formed in the housing and be selectively isolated from the perforation of the housing by valve 459 that fits a seat 452 formed in the housing. Hydraulic fluid may be disposed in the chamber. The lever 455 can extend into the perforation of the housing for fitting through a lower part of the flow tube 410. The lever 455 can be attached to the housing by means of, for example, articulation. The stem 456 may be connected to piston 460 and extend through valve 459 and lever 455. One or more seals (not shown) may (m) be arranged between piston 460 and chamber 451. The stem 456 can be connected to piston 460 by a rack and teeth, so that the rod can move longitudinally upwards with respect to the piston, but not downwards.
During operation, as flow tube 410 is being moved down to open hinge 420, the flow tube can engage lever 455 and rotate the lever around the hinge. The lever 455 can in turn push stem 456 against stem spring 457, thereby causing the stem to pull piston 460 down. Downward movement of piston 460 can increase the pressure in chamber 451, thereby opening valve 459 and expelling one of the 250p RFID tags. The 250p RFID tag can float upwards and / or be carried upwards by the 1045f circulating drilling fluid. The 250p RFID tag can be read by the external antenna 226 o as the tag moves beyond the telemetry sub 200. The telemetry sub 200 can then report to probe 1000. Alternatively, or in addition, the 250p tag can be read on probe 1000. As the hinge 420 completes the opening, a groove 410g formed on an external surface of the flow tube 410 can become aligned with the lever 455, thus allowing the stem spring 457 to reprogram the lever. Disc 460 may remain in the forward position due to the operation of the rack mechanism. During this stroke, the lever that closes 455 can move longitudinally downward; however, as the closing 450c can be reversed from the opening 450o, the rack mechanism can prevent the movement of the closing piston 460, thus ensuring that the closing remains idle. The closing 460c can be operated as the hinge 420 moves from the open to the closed position (having one or more tags 250p written with a message that the hinge is closed). Alternatively, instead of the RFID 250p tags, colored spheres (ie, red for closed and green for open) can be arranged in chambers 451 and observed in probe 1000.
Figures 6A and 6B illustrate an isolation valve 500 in the closed position, according to another embodiment of the present invention. Figure 6C is an enlargement of a portion of Figure 6 A. The isolation valve 500 may include a tubular housing 510, a flow tube 515, a closing member, such as hinge 520, and an actuator 550. As discussed above, the closing member may be a ball (not shown) instead of hinge 520. To facilitate fabrication and assembly, housing 505 may include one or more sections 505a-and each of them connected to the other, secured , for example, with threaded connections and / or fasteners. Housing 505 may further include an upper adapter (not shown) connected to section 505a and a lower adapter (not shown) connected to section 505e for connection as part of the housing or liner. The housing 505 may have a longitudinal perforation formed through it for the passage of a perforation column.
The piston 510 and the flow tube 515 can each be arranged inside the housing 505. The piston 510 and the flow tube 515 can each be movable in the longitudinal direction with respect to the housing 505. The piston 510 and flow tube 515 can be connected together by means of, for example, coupling 512. Piston 510 and flow tube 515 can each be attached to coupling 512, by means of, for example, threads and / or fasteners. The piston 510 may have a projection 510s formed on an external surface thereof. The 510s projection can carry one or more seals to fit an internal surface of a chamber 507 formed in the housing 505. The housing 505 can have projections upper 505u and lower 5051 formed on an internal surface thereof. Chamber 507 can be defined radially between piston 510 and housing 505 and piston 510 and longitudinally between an upper seal disposed between housing 505 and piston 510 near the upper projection 505u and a lower seal disposed between housing 505 and the piston 510 near the bottom projection 5051. The hydraulic fluid can be arranged in the chamber 507. Each end of the chamber 507 can be in fluid communication with the actuator 550 via a respective hydraulic passage 553u, l formed through a wall of the housing 505.
The flow tube 515 can be moved in the longitudinal direction by the piston 510 between the open position and the closed position. In the closed position, the flow tube 515 can be away from the hinge 520, thus allowing hinge 520 to close. In the open position, the flow tube 515 can fit into the hinge 520, push the hinge 520 into the open position, and fit a seat 523 formed in the housing 505. The fitting of the flow tube 515 in the seat 523 can form a chamber 506 between flow tube 515 and housing 505, thereby protecting hinge 520 and hinge seat 522. The hinge 520 can be articulated in the housing 505 by means of, for example, a fastener 520p. A tensioning member, such as a torsion spring 521, can fit into hinge 520 and housing 505 and be arranged around fastener 520p to tension hinge 520 in the closed position. In the closed position, the hinge 520 can fluidly isolate an upper portion of the valve from a lower portion of the valve.
Actuator 550 may include electronics housing 525, battery 531, antenna 526, electric motor 558, hydraulic pump 552, and position sensor 555. The electronics housing 525 and antenna 526 may be similar packaging of electronic components 225 and antenna 226i, respectively. The pump 552 can be in communication with the passages 553u, l and operable to hydraulically move the projection 510s longitudinally between the closed position and the open position. The 552 pump may include a piston and cylinder and connected to the 558 engine by a nut and a guide screw. Alternatively, the 558 motor can be a linear motor instead of a rotary motor. In addition, the actuator 550 can include a 557 solenoid operated valve or a solenoid operated latch to close the valve in the open and closed positions to avoid unintentional actuation of the valve due to accidental contact with the drill string.
The 558 electric motor can drive the 552 hydraulic pump when receiving electricity from the microprocessor. The microprocessor can supply electricity in a first polarity to open hinge 520 and a second inverted polarity to close hinge 520. Position sensor 555 may be able to detect when the piston is in the open position, in the closed position, or in any position between the open and closed positions so that the microprocessor can detect the total or partial opening of the valve. The 555 position sensor can be a Hall sensor and a magnet or a linear voltage differential transformer (LVDT). The 555 position sensor can be in electrical communication with the microprocessor via 554s conduits. The microprocessor can use the position sensor 555 to determine when the piston projection 510s has reached the open or closed position to stop the engine 558 and close the valve 557. Antenna 526 can be joined or attached to an internal surface of housing 505 and in electromagnetic communication with the perforation of the housing. Antenna 526 may be in electrical communication with the microprocessor via conduits 554a. The packaging of electronic components 525, engine 558, pump 552, and valve 557 can be molded into a field replaceable unit and attached to a recess formed on an external surface of housing 505.
In operation, to open or close valve 500, an RFID instruction tag, such as the passive tag 250p, can be pumped through drill string 1050 and exit drill string 1050 via drill bit 1050b. The tag 250p can then be carried over the annular space 1025 above until the tag is in range of the antenna 526. The microprocessor can read the command encoded in the tag 250p, for example, to open the valve. The microprocessor can then open valve 557 and operate engine 558, thus moving the piston projection 510s and flow tube 515 to fit with hinge 520. The microprocessor can then detect that hinge 520 has been opened. A verification RFID tag, such as the WISP 250w tag, can then be pumped through the drill string 1050 and return through the annular space 1025. The WISP 250w tag can inquire about the position of the hinge 520 (as measured indirectly by the heading 555). The microprocessor can then respond that hinge 520 is open or respond with an error message if actuator 550 has malfunctioned and has not opened hinge 520. The WISP 250w tag can record the response and continue to probe 1000 where a surface reader can retrieve 250w tag information. The error message may include the position of the piston projection 510s (the drilling operation can continue even if the hinge 520 is open, but not completely covered by flow tube 515). Closing the hinge can be similar to opening. In addition, the WISP 250w label can inquire and record a battery charge level.
Alternatively, instead of pumping tags to communicate with isolation valve 500, telemetry sub 200 can be included in drill column 1050 and used to send the instruction signal to the valve microprocessor and receive status information . The telemetry sub 200 can then communicate status information to probe 1000. Alternatively, piston 510 can be a mandrel having gear teeth formed along an outer surface of it and pump 552 can be replaced with a gear that connects the 558 motor to the chuck. Alternatively, instead of pumping tags to communicate with the isolation valve 500, the packaging of the electronics 525 may include a vibration sensor in communication with the microprocessor and the instruction signal can be sent to the microprocessor by labeling the enclosure according to a predetermined protocol. The labeler can be located on the surface (that is, on the surface of the well) and be operated by the probe controller.
Figure 7A illustrates another way of operating the isolation valve 550, according to another embodiment of the present invention. Instead of pumping the labels through the perforation column 1050, two or more labels 601o, c, such as passive labels 250p, can be embedded in an external surface of the perforation column 1050. The labels 601o, c may be embedded in an external surface of the drill bit 1050b, a drilling of the drill string 1050 near the drill bit, such as a drill string, or a portion of the drill string furthest from the drill bit, such as the first joint of the drill pipe connected to the drill collar. The tags 601o, c can be spaced far enough apart that the tags are not simultaneously in the range of the antenna 526. Tag 601o can be written with the open remote and tag 601c can be written with the closed remote. As the drill string 1050 is lowered down to the antenna range 526, the microprocessor can read the close command first from the 601c tag and simply ignore the command once the microprocessor knows that valve 500 is already closed. The microprocessor can then read the open command from label 601o and open valve 500. On the contrary, when retrieving drill column 1050 from well hole 1005 (hinge 520 is open), the microprocessor can read the open command first and ignore the command since the microprocessor knows that valve 500 is already open. The 32/65 microprocessor can then read the closed command and close the hinge 520 accordingly. If, as discussed below, housing 1015 was cemented with hinge 520 open, the hinge can close when actuator 550 receives the close command and then open when the actuator receives the open command.
Alternatively, each of the labels 601o, c may be arranged on a fastener, such as a snap ring (not shown), attached to an outer surface of the drill string. Each snap ring may include a plurality of open labels 601o or closed labels 601c spaced around it for repetition. Each label can be joined in a recess formed on an external surface of the pressure ring, by means of, for example, epoxy. Each pressure ring can be formed of a hard material to resist erosion during drilling, such as steel, ceramic or tool cermet. Alternatively, an upper portion of valve 500 including actuator 550 and piston 510 may be a sub power divided by a lower portion of the valve including hinge and flow tube by a spacer sub. In this alternative, the flow tube may include a piston projection in communication with the piston. Alternatively, each of the 601o, c tags can be a WISP 250w tag and can record a valve battery position and / or status to be read when the drill string is retrieved on probe 1000.
Figure 7B illustrates a charger 600 for use with an isolation valve 500a, in accordance with another embodiment of the present invention. Figure 7C is an isometric view of the charger 600. In the event that the battery 531 of the actuator 550 runs out, a charger 600 can be added to the drill string 1050. The charger 600 can include a tubular housing 605 having threaded couplings formed on each longitudinal end of the same for connection to other components of the drill string 1050. The housing 605 can include one or more sections (only one section shown) to facilitate fabrication and assembly, each section connected to the other, secured, for example, with threaded connections.
The housing 605 may have a longitudinal perforation formed through it and one or more compartments formed in a wall thereof. A packaging for electronic products 625 (similar to packaging for electronic products 225) and a battery 631 can each be arranged in a respective compartment. The microprocessor of the charger and the 631 battery can meet with electrical communication via internal conduits (not shown). An antenna 626 (similar to antenna 226o) can be arranged around an external surface of the charging housing 605.
Valve 500a can be similar to valve 500, except that an indicator 560, such as a passive RFID tag 250p, can be embedded in an internal surface of the valve housing 505 and a jacket 565 can be added over the antenna. valve 526. The liner 565 can be attached to the valve housing 505 by means of, for example, a threaded connection. The 565 jacket can be made of an electrically conductive, non-magnetic metal or alloy, such as copper, copper alloy, aluminum, aluminum alloy, or stainless steel. The jacket 565 can be divided into two poles by a dielectric material (not shown). The jacket 565 can be in electrical communication with the valve microprocessor via conduits (not shown). Indicator 560 may be located near valve antenna 526.
One or more reinforcements 605r can be formed on an external surface of the housing 605 and be (are) spaced around it. A contact, such as a lamellar spring 607, can be attached to housing 605 and extend from each reinforcement 605r. Each 607 contact can be in electrical communication with the charger's microprocessor via internal conduits (not shown). In operation, the charger's microprocessor can detect indicator 560 and respond by supplying DC electricity from battery 631 to two of the 607 contacts. An opposite polarity can be provided for the other two 607 contacts. The resulting current can flow through the contacts 607 and jacket 565 for the valve microprocessor. Electricity can also charge the 531 valve battery. The charger microprocessor and the valve microprocessor can also communicate via contacts 607 and jacket 565. The charger microprocessor can periodically query the valve microprocessor for a battery charge state and periodically question indicator 560. The microprocessor can turn off electricity when valve battery 531 is fully charged or when indicator 560 is out of reach of antenna 626 on the charger. During or after loading, a 250p RFID tag can be pumped through the drill string 1050 to open or close the hinge 520.
Alternatively, contacts 607 can be replaced with antenna 626 and jacket 565 can be omitted. Antenna 626 can be used to charge the valve battery via inductive coupling between antenna 626 and valve antenna 526 or a coil can be added to the valve for charging. Alternatively, a capacitor (not shown) can be used instead of the 531 battery. The capacitor can then be charged each time you want to open or close the 500 valve. The capacitor can also be used in addition to the 531 battery as a backup in the case of battery fails. In addition, loader 600 may include mud pulser 275 to report to the drill rig and / or tachometer 255 and pressure sensor 204 to receive valve instruction signals from the drill rig and relay the signals to the valve insulation rather than pumping RFID tags to send the signals.
Figure 7D illustrates another charger 650 for use with an isolation valve 500b, according to another embodiment of the present invention. Valve 500b may be similar to valve 500, except that 560u, l indicators, such as passive RFID tags 250p, may be embedded in an inner surface of the valve housing 505 and an inner surface of the piston 510. The charger 650 may include a tubular housing 655 having threaded couplings formed at each longitudinal end thereof for connection to other components of the 1050 drill string. Housing 655 can include one or more sections (only one section shown) to facilitate fabrication and assembly, each section connected the other, through, for example, threaded connections. The housing 655 can have a longitudinal perforation formed through it and one or more compartments formed in a wall thereof. The packaging of electronic products 625 and battery 631 may be in electrical communication via internal conduits (not shown). Antenna 626 can be arranged around an external surface of the charger housing 605.
Charger 650 may be similar to charger 600, except that instead of contacts 607, charger 650 may include one or more electromagnets 660. Electromagnet 660 may be arranged in an external compartment formed in housing 655 and includes a winding. Winding 660 may include wire or strip wound (a) around an inner surface of housing 655 in a helical spiral and made of conductive material, such as aluminum, copper, aluminum alloy, or copper alloy. Each turn of the spiral can be electrically isolated by a dielectric material, such as tape, or the conductive material can instead be anodized. Winding 660 can be isolated from housing 655 by the dielectric material. The housing 655 may be made of a ferromagnetic material, such as a metal or an alloy, such as steel, to serve as the core of the electromagnet 660. Alternatively, the electromagnet 660 may include one or more toroidal windings arranged in the housing compartment. Each toroidal winding can include a winding wound around a core ring made from ferromagnetic material and the housing can be made from ferromagnetic material or a non-magnetic material.
In operation, as the drill string 1050 is being longitudinally raised or lowered through the isolation valve 500b, the charger's microprocessor can read a corresponding 560u, l indicator label. The microprocessor of the charger can then supply DC electricity from the battery 631 to the electromagnet 660. As the electromagnet 660 is longitudinally raised or lowered by the valve antenna 526, a DC voltage (electromotive force) can be generated in the antenna accordingly. with Faraday's law (analogous to a Faraday flashlight (the dynamo)). The resulting electricity can charge battery 531 of the valve. The microprocessor in the charger can continue to supply electricity to the 660 electromagnet until the microprocessor detects the other label on the 560u indicator, l. The microprocessor can then turn off the electricity to the electromagnet 660, so that the electromagnet does not attract chips during drilling. The charger's microprocessor can switch the polarity provided for the electromagnet based on which indicator is first detected, thereby avoiding the need for the 525 valve's electronic components to include a rectifier. A 250w status tag can then be circulated through the 1050 drill string to obtain a battery charge status for the valve. If a single passage of drill string 1050 is insufficient to charge battery 531 of the valve, then the drill string can be reciprocated on valve 500 until the battery of the valve is fully charged.
Alternatively, a plurality of loaders 650 can be deployed along the drill string 1050 at regular intervals, such as one every thousand feet, so that while drilling well 1005 is being drilled or the drill string is being recovered, the 531 valve battery receives a charge intermittently.
Figure 7E illustrates another charger 575 for use with an isolation valve 500c, according to another embodiment of the present invention. Figure 7F is an enlargement of charger 575. Figure 7G is a cross-section illustrating two layers 587 of charger 575. Except for the addition of charger 575, valve 575 may be similar to valve 500. Charger 575 may be a thermoelectric generator and may include a substrate 580 made of thermally insulating dielectric, such as a ceramic disk having a microporous structure, one face of which holds type n 585n and type p 585p semiconductor members.
The semiconductor members 585n, p can be placed alternately and electrically connected in series with each other to form thermocouples 586c, h at their junctions. Each member 585n, p may include a portion of straight bar that extends transversely to the longitudinal direction of the substrate 580 and two bars perpendicular opposite each other and located at respective ends of the portion of straight bar, thus forming a member in the shape of a Z. Each 585n, p member can be made of a thin film of n-type doped or p-type doped polycrystalline semiconductor ceramics. The joints formed between the semiconductor members 585 n, p can alternate from one side of the longitudinal median geometric axis of the substrate 580 to the other, to form the respective hot 586h and cold 586c junctions of the thermocouples. The materials of the substrate 580 and semiconductor members 585n, p can be chosen so as to have compatible thermal expansion coefficients in order to avoid high thermal stresses in the components of the generator 575 during use.
The generator 575 may include one or more layers 587 stacked in such a way that the semiconductor members 585n, p carried by one substrate 580 are covered by another substrate 580 of the same type and size. Each semiconductor member 585n, p of each layer 587 can be thermally connected to substrates 580 in parallel with the other members of the layer. Each layer 587 can be thermally connected in parallel with the other layers. The number of substrates 580 may be greater than that of components, so that the semiconductor members of all components are covered by a dielectric substrate 580. The generator may include electrical connections, such as two bands that connect 590 (only one shown ), made of electrically conductive material. Each band 590 can connect cold junction ends 586c of the layers electrically in series or in parallel and the electrical conduits can connect the bands to the microprocessor and / or battery 531. The thermal generator 575 can be connected or attached to an internal surface of the housing 505 and connected to the microprocessor and / or battery via electrical conduits (not shown).
In operation, an external surface of valve 500c may be at an ambient temperature from the well bore. To charge battery 531, drilling fluid 1045f having a temperature that is lower or substantially lower than the ambient temperature of the well hole can be pumped through the drilling column 1050 and into the annular space 1025, thereby inducing a gradient temperature throughout the generator 575. Due to the Peltier-Seebeck effect, a voltage can be generated by the 585n, p semiconductor members, thus charging the battery 531. The temperature gradient between drilling fluid 1045f at ambient surface temperature and well hole temperature may be sufficient to charge the 531 battery.
Figures 8A-8C illustrate another insulation assembly in the closed position, according to another embodiment of the present invention. The insulation assembly can include a power sub 700, the spacer sub 25, and the isolation valve 50. The insulation assembly can be mounted as part of an enclosure 1015 or seal liner and inserted into well bore 1005 The casing 1015 or seal liner column can be cemented into the well bore or be a connector liner column.
The power sub 700 can include a tubular housing 705, a tubular mandrel 710, and an actuator 750. The housing 705 can have couplings (not shown) formed at each of its longitudinal ends for connection with other components of the enclosure column. cro / coating. Couplings can be threaded, such as a box and a pin. Housing 705 may have a central longitudinal perforation formed therethrough. Although shown as one piece, the 705 housing can include two or more sections to facilitate fabrication and assembly, each section connected to the other, through, for example, threaded connections.
Mandrel 710 can be arranged within housing 705 and can be moved longitudinally with respect to it between an upper position (shown) and a lower position. The mandrel 710 may have a lower profile 7111 formed on an internal surface of the mandrel to receive a strut from the deflection tool (not shown). The bypass tool can be similar to the bypass tool 100, except that actuator 150 can be omitted and a seat can be formed on an internal surface of the bypass tool mandrel to receive a locking member, such as a sphere 1090 (Figure 11A), implanted along the 1050 drill column for its operation. The 1090 ball can be deployed by pumping or pouring. Although not shown, mandrel 710 may still have one or more position indicators similar to the 15p, l, h, discussed above. The mandrel 710 can also have a piston projection 710s formed on an external surface of it or attached to it. The piston projection 710s can be arranged in a 706 chamber. The housing 705 can also have projections upper 705u and lower 7051 formed on an internal surface of the same. Chamber 706 can be defined radially between mandrel 710 and housing 705 and longitudinally between an upper seal disposed between housing 705 and the mandrel near upper projection 705u and a lower seal disposed between housing 705 and mandrel 710 near projection lower 7051. Hydraulic fluid may be arranged in chamber 706. Each end of chamber 706 may be in fluid communication with a respective hydraulic coupling 709c via a respective hydraulic passage 709p formed longitudinally through a wall of housing 705.
The driver 705 may include an antenna 726, an electronics housing 725, a battery 731, a lock 752, a latch 754, a position sensor 755 and a tensioning member, such as a coil spring 756. The antenna 726 and the packaging of electronic products 725 can be similar to the antenna 226i and the packaging of electronic products 225, respectively. The spring 756 can be arranged in the chamber 706 against the upper projection 705u and an upper part of the projection 710s, thus tensioning the mandrel 710 in the direction of the lower position in which the valve 50 is opened. Chuck 710 can be selectively restricted in the open position (where valve 50 is closed) by latch 754 and lock 752. Latch 754 can be a clamp connected to the housing, for example, being attached to it. The clamp may include a base ring and two or more radially split fingers. The mandrel 710 can have an upper profile 711u formed on an external surface of it to receive the fingers, thus longitudinally connecting the mandrel 710 and the housing 705. The fingers can be tensioned to fit with the profile 711u. The tensioning of the spring may be sufficient to direct the clamp fingers from the top profile 711u.
Lock 752 may include a linear actuator, such as a linear motor, and a longitudinally movable jacket with respect to the housing near the linear actuator between a locked position and an unlocked position. The jacket can fit an external surface of the forceps fingers in the closed position, thus preventing the fingers from moving radially out of the upper profile. The shirt may be removed from the fingers in the unlocked position, thus allowing the fingers of the clamp to move radially out of the upper profile. The linear actuator can be attached to the housing and in electrical communication with the packaging of the 725 electronic products through internal conduits. The 755 position sensor can be a Hall sensor and magnet or a linear voltage differential transformer (LVDT). The 755 position sensor may be in electrical communication with the microprocessor via conduits. The microprocessor can use the 755 position sensor to determine when the upper profile is aligned with the pincer fingers to extend the shirt and close the pincer fingers in the profile. The microprocessor can also use the position sensor to check that the valve has opened. Antenna 726 can be connected or attached to an internal surface of housing 705 and in electromagnetic communication with the perforation of the housing. Antenna 726 may be in electrical communication with the microprocessor via conduits.
In operation, to open valve 50, an RFIS instruction label, such as passive label 250p, can be pumped through drill column 1050 and exit the drill column via drill bit 1050b. The tag 250p can then be carried over the annular space 1025 above until the tag is in range of the antenna 726. The microprocessor can read the command encoded in the tag 250p, in order to open the valve. The microprocessor can move the jacket to the closed position supplying electricity to the linear actuator, thus allowing the 756 spring to move the 710s piston projection downwards and open valve 50. The movement of the 710s piston projection can be dampened by a damper, such as an orifice 740, arranged in passage 709p. The microprocessor can then detect that valve 50 has opened. A check RFID tag, such as the WISP 250w tag, can then be pumped through the drill string 1050 and return annular space 1025 above. The WISP 250w tag can inquire about the position of valve 50. The microprocessor can then respond that hinge 70 is open or respond with an error message if actuator 750 has malfunctioned and valve 50 has not opened. The WISP 250w label can record the response and continue to probe 1000 where a surface reader can retrieve the 250w tag information. The error message may include the position of the piston 710s projection (the drilling operation can continue even if the hinge 70 is open, but not completely covered by the flow tube 60). In addition, the WISP 250w label can inquire and record a charge level for the battery.
To close valve 50 after a drilling operation, drill column 1050 can be raised until the deflection tool prop is aligned with the bottom profile 7111. An RFID instruction tag, such as the passive tag 250p, can be pumped through the drill string 1050 and exit the drill string with the drill bit 1050b. The tag 250p can then be carried over the annular space 1025 above until the tag is in range of the antenna 726. The microprocessor can read the command encoded on the tag 250p, in order to close valve 50. The microprocessor can supply electricity to the linear actuator, thus unlocking the jacket. Ball 1090 can then be launched from probe 1000 and pumped down through drill column 1050 until the ball falls into the seat of the deflection tool. Continued pumping can exert fluid pressure on the 1090 ball, thus driving the chuck of the deflection tool down longitudinally and moving the internal serrations of the deflection tool with respect to the external serrations. Once the 1090 ball has fallen and the knurls are operated, pumping can be stopped and pressure maintained. Bypass tool holders can be wedged out by the relative longitudinal movement of the serrations. Bypass tool holders can push the school to engage with an inner surface of mandrel 710. If the strut is misaligned with the lower profile 7111, then the bypass tool can be raised and / or lowered until the strut is aligned with the profile. The lamellar spring of the deflection tool can allow the strut to be pushed in by the profile while the profile engages with the strut. The support of the strut with the profile 7111 can connect the deflection tool and the mandrel 710 longitudinally. The deflection tool can be lifted, thus lifting the mandrel 710 against the spring 756 until the clamp fingers are aligned and fit in the profile 711u. The microprocessor can detect the fit using the position sensor and turn off the electricity to the microprocessor, thus locking the jacket.
Alternatively, the embedded tags 601o, c can be used to send open and / or closed commands. In addition, any of the 600, 650, 575 chargers can be used to charge the battery 731 and a capacitor can be used in place of the battery or in conjunction with the battery as discussed above.
Figures 9A-C illustrate another insulation assembly in the closed position, according to another embodiment of the present invention. The insulation assembly may include a sub-power 800, the spacer sub 25, and the isolation valve 50. The insulation assembly may be mounted as part of a 1015 enclosure or sealing liner and placed within the hole of well 1005. Housing 1015 or the sealing liner can be cemented into well bore 1005 or be a connector housing column.
Power sub 800 can include a tubular housing 805, a hydraulic pump, and an actuator 850. Housing 805 can have couplings (not shown) formed at each longitudinal end of it for connection to other components of the enclosure / casing column . The couplings may have a central longitudinal perforation formed through it. Although shown as one piece, the 705 housing can include two or more sections to facilitate fabrication and assembly, each section connected to another, secured, for example, by threaded connections. The housing 805 may have a piston chamber 805c, an accumulator chamber 820a, and a reservoir chamber 820r formed therein and one or more ports 805p that provides fluid communication between the perforation of the housing and the piston chamber 805c. Hydraulic fluid can be disposed in chambers 805c, 820a, r. The housing may also have hydraulic passages 809u, l formed through it providing fluid communication between the actuator and the respective hydraulic couplings 809c. Hydraulic couplings 809c can be connected to respective hydraulic couplings of spacer sub 29c. The passage 809u can provide fluid communication between the actuator 850 and an upper portion of the valve chamber 57 and the passage 8091 can provide fluid communication between the actuator and a lower portion of the valve chamber (via spacer sub 25 and respective passages 59p ).
The hydraulic pump may include piston chamber 805c, piston 810, and check valves 815a, with a tensioning member, such as a helical spring 830. Alternatively, the hydraulic pump may include a diaphragm instead of piston 810. The piston 810 can be arranged in piston chamber 805c and carry a seal on its inner and outer surfaces to fit the wall of the piston chamber. The piston 810 can divide the piston chamber 805c into upper and lower portions. The spring 830 can be arranged in the lower portion of the piston chamber and can tension the piston towards ports 805p. The hydraulic fluid can be arranged in the lower portion of the piston chamber 805c.
The upper piston chamber portion may be in fluid communication with the housing bore via ports 805p and the lower portion may be in communication with the check valve 815a via a hydraulic passage 808 a formed longitudinally through a wall of the housing 805. The passage 808a can also provide fluid communication between the check valve 815a and the accumulator chamber 820a and between the accumulator chamber and the actuator 850. The check valve 815a can be operable to allow the flow of hydraulic fluid through it from the lower portion of the piston chamber to the accumulator chamber 820a and avoid an inverted flow through it. The lower piston chamber portion can also be in communication with a check valve 815r via a hydraulic passage 808r formed longitudinally through a wall of housing 805. The passage 808r can also provide fluid communication between the check valve 815r and the reservoir chamber 820r r between reservoir chamber and actuator 850. Check valve 815r can be operable to allow hydraulic flow to flow through it from reservoir chamber 820r to the bottom portion of the piston chamber and prevent inverted flow through of the same.
Each of the chambers of accumulator 820a and reservoir 802r can include a divider, such as a floating piston, bellows, or diaphragm, dividing each chamber into a gas portion and a hydraulic portion. A gas, such as nitrogen, may be disposed in the gas portion and fluid and hydraulic fluid may be disposed in the hydraulic portion.
In operation, the hydraulic pump can use fluctuations in drilling the housing (housing) to pressurize the 820a accumulator chamber. For example, as drilling fluid 1045f is circulated to drill well bore 1005, friction due to returns 1045r flowing through annular space 1025 above and / or use of choke 1065 can substantially increase the pressure in drilling compared to hi pressure. -drostatic. The drilling pressure can cause longitudinal movement of the piston 819 downwards against the spring 830, thus forcing the hydraulic fluid through the check valve 815a into the accumulator 820a. Once the pressure in the drilling is reduced, the spring 830 can reprogram piston 810. As piston 810 moves longitudinally upwards during drilling, the piston can draw hydraulic fluid from reservoir 820r through check valve 815r . The accumulator chamber 820a can store fluid energy until it is time to open or close valve 50. Accumulator 820a can store enough fluid energy for one or more strokes of valve 50.
Figures 9D and 9E illustrate the operation of actuator 850. Actuator 850 may include an antenna 826 (Figure 8A), a packaging for electronics 825, a battery 831, an electric motor 852, a gearbox 854, and one or more tripartite valves 855a, r. The antenna 826 and the packaging of electronic products 825 can be similar to the antenna 226i and the packaging of electronic products 225, respectively. Each of the tripartite valves 855a, r can be in fluid communication with the passages 808a, r, the accumulator chamber 820a, and the reservoir chamber 820r via hydraulic passages formed on a wall of the housing 805. Gearbox 854 may include a drive clutch rotatably connected to motor 852 and a valve gear fitted to each of the three-way valves 855a, r. Gearbox 854 can convert the rotation of motor 852 around a first geometry axis into rotation of each of the valves around a second geometry axis.
In operation, to open the isolation valve 50, an RFID instruction tag, such as the passive tag 250p, can be pumped through the drill string 1050 and exit the drill string by the drill bit 1050b. The 250p tag can then be carried over the annular space 1025 above until the 250p tag is out of reach of the antenna. The microprocessor can read the command encoded on the tag 250p in order to open valve 50. The microprocessor can supply electricity to motor 852 at a first polarity. Motor 852 can rotate valves 855a, r (via gearbox) from the position in Figure 9E to the position in Figure 9D. The 852 motor may include a rotor position sensor in communication with the microprocessor to indicate when the motor has fully rotated the 855a, r valves. The microprocessor can then turn off the electricity to the engine when the valves have reached the position shown in Figure 9D. The accumulator chamber 820a can then supply pressurized hydraulic fluid to the piston 61 projection via passage 809u, thus moving the flow tube 60 down to the hinge 70 hinge. The returned fluid can flow from the valve chamber 57 to the accumulator 820a via passage 8091. Once isolation valve 50 is opened, tripartite valves 855a, r can be left in the position of Figure 9D until the microprocessor receives a close command.
In operation, to close the isolation valve 50, an RFID instruction tag, such as the passive tag 250p, can be pumped through the drill string 1050 and exit the drill string by the drill bit 1050b. The tag 250p can then be carried over the annular space 1025 above until the tag is in range of the antenna 826. The microprocessor can provide electricity to the motor 852 at a second polarity opposite to the first polarity. The 852 engine can rotate the valves (via gearbox) from the position in Figure 9D to the position in Figure 9E. The microprocessor can then turn off electricity to motor 852 when valves 855a, r reach the position shown in Figure 9E. The accumulator chamber 820a can then supply pressurized hydraulic fluid to the piston projection 61 through passage 8091, thus moving the flow tube 60 up out of engagement with the hinge 70. The returning fluid can flow from the valve chamber 57 to the accumulator via 809u passage. Once isolation valve 50 is opened, tripartite valves 855a, r can be left in the position of Figure 9E until the microprocessor receives an open command.
In addition, the actuator may include a flow meter (not shown) arranged in one or both passages 809u, l and in electrical communication with the microprocessor to serve as a position indicator. The RFID verification tag, such as the WISP 250w tag, can then be pumped through drill column 1050 and return annular space 1025 above after valve 50 has been closed or opened to check the position of the valve. Alternatively, the embedded tags 601o, c can be used to send open and / or closed commands. In addition, any of the 605, 650, 575 chargers can be used to charge the 831 battery and a capacitor can be used instead of the battery or in addition to the battery, as discussed above. Alternatively, the spacer sub 25 can be omitted and the power sub 800 can be incorporated into the isolation valve 50.
Figure 10A illustrates a portion of another isolation valve 900a in the closed position, respectively, according to another embodiment of the present invention. Isolation valve 900 a can be used in the isolation assembly of Figures 1 A-C to replace a lower portion (Figure 1C) of isolation valve 50.
Isolation valve 900a may include a tubular housing 905a, a flow tube 910, and a closing member, such as hinge 920. As discussed above, the closing member may be a ball (not shown) instead of the hinge 920. To facilitate manufacturing and assembly, housing 905 may include one or more sections 905a-d each connected to the other, secured, for example, with threaded connections and / or fasteners. The 905 housing may also include a lower adapter (not shown) connected to section 905b for connection to the housing or to the sheath. The housing 905 may have a longitudinal perforation formed through it for the passage of a perforation column. Flow tube 910 can be moved longitudinally with respect to housing 905.
The flow tube 910 can be moved longitudinally by the piston between the open position and the closed position. In the closed position, the flow tube 910 can be away from the hinge 920, thus allowing the hinge 920 to close. In the open position, the flow tube 910 can fit the hinge 910, push the hinge 920 to the open position, and fit a seat 906s formed in a lower part of the housing section 905c and attached to it. The fitting of the flow tube 910 with the seat 906s can form a chamber 906 between the flow tube 910 and the housing 905, thus protecting the hinge 920 and the hinge seat 906s. The hinge 920 can be hinged to the housing 905, using, for example, a fastener 920p. A tensioning member, such as a torsion spring 921, can fit into hinge 920 and housing 905, and be arranged around fastener 920p to tension hinge 920 in the closed position. In the closed position, hinge 920 can fluidly isolate an upper portion of the valve from a lower portion of the valve.
The valve 900a may further include one or more sensors, such as a pressure sensor 904u, a lower pressure sensor 9041, a flow tube position sensor 912t, and a hinge proximity sensor 904f. Valve 900a may further include packaging for 925 electronic components, antenna 926, and battery 931. Antenna 926 and packaging for electronic components 925 may be similar to antenna 226i and packaging for electronic components 225, respectively. The flow tube 910 can be made of a metal or non-magnetic alloy (a), such as stainless steel, so as not to obstruct the reception of the antenna. The upper pressure sensor 904u may be in fluid communication with the housing bore above the hinge 920 and the lower pressure sensor 9041 may be in fluid communication with the housing bore below the hinge. Flow tube 910 can allow leakage, so as not to fluidly isolate pressure sensors 904u, l. The 904u, l pressure sensors can also be operable to measure temperature. Lead wires 909a can provide electrical communication between the microprocessor and sensors 904u, l, 912f, t. The 912t position sensor and the 912f proximity sensor can each be a Hall sensor and magnet, or the position sensor can be a linear voltage differential transformer (LVDT). Alternatively, the 912f proximity sensor can be a contact switch. The flow tube position sensor 912t may be able to detect when flow tube 910 is in the open position, in the closed position, or in any position between the open and closed positions, so that the microprocessor can detect the full opening or partial valve. The hinge proximity sensor 912f can detect the hinge closing. The hinge sensor 912f may be in electrical communication with conduits 909a via contacts 913.
In operation, instead of using position indicator 151 to check the opening or closing of the valve, a check label, such as the WISP 250w label, can be pumped through the drill string and return the annular space above. The valve microprocessor can read the position investigation command encoded on the WISP 250w tag and report the position of the valve 50 using the position sensors 912t, f. The WISP 250w tag can record the response and continue to the telemetry sub 200. The telemetry microprocessor can read the position from the 250w tag and report to probe 1000. The WISP tag can also investigate the pressure and temperature above and / or below the hinge, record the pressure and temperature, and report the pressure and temperature to the telemetry microprocessor.
Alternatively, instead of pumping the WISP 250w tag, the drill string can include one or more WISP 250w tags similar to the 601c tag. The tag can then be read when drill string 1050 is retrieved to probe 1000. Alternatively, antenna 926 can be located in power sub 1 and conduits 909a can extend from valve 900 a to the power sub so that the 926 antenna can be used to communicate with the telemetry sub.
Figure 10B shows a portion of another isolation valve 900b in the closed position, respectively, according to another embodiment of the present invention. Isolation valve 900b can replace a lower portion (Figure 6B) of any of the isolation valves 500, 500a, 500b. Isolation valve 900b can also be used in the isolation assembly of Figures 8A-C or 9A-C to replace a lower portion (Figure 8C or 9C) of isolation valve 50. Isolation valve 900b can be similar to the isolation valve insulation 900a except where the antenna, electronics packaging, and the battery can be omitted so that conduits 909b extend for electronics packaging 525, 725, 825 of the respective valves or power subs. In this way, the position and pressures can be reported as discussed above. Alternatively, the 904u pressure sensor can be used to receive pressure pulses sent from the drill rig to carry instructional signals instead of the RFID tag. In addition, pressure signals and the RFID tag can be used to send the signals and valve 909b may not execute the command until it receives both signals.
Alternatively, isolation valve 400 can replace a lower portion (Figure 6B) of any of the isolation valves 500, 500a, 500b.The isolation valve 900b can also be used in the isolation set of Figures 8A-C or 9A-C to replace a lower portion (Figure 8C or 9C) of isolation valve 50.
Figure 11A illustrates a drilling rig 1000 for drilling a well hole 1105 according to another embodiment of the present invention. The drilling rig 1000 can be implanted on land or at sea. If well bore 1005 is below sea level, drilling rig 1000 may then be a mobile offshore drilling unit, such as a drill or semi-submersible vessel. The drilling rig 1000 can include a drilling tower 1004.The drilling rig 1000 can also include a main winch 1024 to support an upper drive 1006. The upper drive 1006 can, in turn, support and rotate a drill column 1050 Alternatively, a Kelly and a turntable (not shown) can be used to rotate the drill string instead of the top drive. The drilling rig 1000 can also include a platform pump 1018 operable to pump drilling fluid 1045f from the well or tank 1008, through a vertical slurry piping and Kelly hose for upper drive 1006. The drilling fluid 1045f can include a liquid foundation. The liquid base can be refined oil, water, brine, or a water / oil emulsion. The drilling fluid 1045f can further include solids dissolved or suspended in the liquid base, such as organophilic clay, lignite, and / or asphalt, thus forming a sludge. The drilling fluid 1045f may further include a gas, such as diatomic nitrogen mixed with the liquid base, thus forming a mixture of two phases. If the drilling fluid is two-stage, the drilling rig 1000 may also include a nitrogen production unit (not shown) operable to produce pure nitrogen commercially from air. The drilling rig 1000 may also include a launcher 1002, a programmable logic controller (PLC) 1070, and a pressure sensor 1028. The pressure sensor can detect impulses from the sludge sent from the telemetry sub 200. The PLC 1070 can be in data communication with the platform pump 1018, the launcher 1002, the pressure sensor 1028, and the upper drive 1006. The platform pump 1018 and / or the upper drive 1006 can (m) include a variable speed drive so that the PLC 1070 can modulate 1095 a flow rate of the platform pump 1018 and / or an angular speed (RPM) of the upper drive 1006. Modulation 1045 can be a square, trapezoidal, or sinusoidal wave. Alternatively, PLC 1070 can modulate the platform pump and / or the ac superior ionization simply by turning them on or off.
Figures 11B-11l illustrate a method of drilling and completing a well hole using the drilling rig 1000. An upper section of a well hole 1005 through a non-productive 1030n formation was drilled using the drilling rig 1000. casing 1015 was installed in well bore 1005 and cemented 1010 in place. One of the isolation / assembly valve discussed and illustrated above was assembled as part of the housing column 1015 and is represented by a hinge 1020. Alternatively, as discussed above, the isolation / assembly valve can be assembled instead as part of a connector casing column received by a polished drilling vessel from a sealing liner column cemented to the well hole. The isolation valve 1020 can be in the open position, for the implantation and cementation of the enclosure column.
Once the casing column has been implanted and cemented, a 1050 drilling column can be implanted in the well bore for drilling a formation of a productive hydrocarbon bearing (ie, crude oil and / or natural gas) 1030p.
The drilling fluid 1045f can flow from the vertical mud implantation pipe and into the drilling column 1050 through a swivel (Kelly or higher unit, not shown). The drilling fluid 1045f can be pumped down through the drill column 1050 and out through a drill bit 1050b, where the fluid can circulate the chips away from the drill 1050b and return the chips to an annular space 1025 formed between an inner surface the casing 1015 or the well bore 1005 and an outer surface of the drilling column 1050. The return mixture (returns) 1045r can return to a surface 1035 of the earth and be deflected through an outlet 1060o of a rotary control device ( RCD) 1060 and for a primary return line (not shown). The 1045r returns can then be processed by one or more separators (not shown). The separators can include a shale shaker to separate the chips from the returns and one or more fluid separators to separate the returns in gas and liquid and the liquid in water and oil.
The RCD 1060 can provide an annular seal 1060s around the drill string 1050 during drilling and while adding or removing (ie, during a maneuvering operation to change a worn drill bit) the segments or supports to / from the drill string. drilling 1050. The RCD 1060 achieves fluid isolation by laying out around the 1050 drill string. The RCD 1060 can include a pressure containment housing mounted in the well bore, where one or more 1060s sealing members are supported between the bearings and insulated by means of mechanical seals. The RCD 1060 can be either an active or a passive type. The active type RCD uses external hydraulic pressure to activate the 1060s sealing members. The sealing pressure is usually increased as the pressure of the annular space increases. The passive type RCD uses a mechanical seal with the sealing action supplemented by the pressure of the well hole. If the 1050 drill string is a spiral tube or other non-articulated tubular, a poor or limb well (not shown) can be used instead of RCD 1060. One or more overflow safety systems (BOPs) 1055 can be fixed to the well bore 1040.
A 1065 variable choke valve can be arranged on the return line. The choke 1065 can be in communication with a programmable logic controller (PLC) 1070 and fortified to operate in an environment where the 1045r returns contain substantial drilling chips and other solids. The choke 1065 can be used during normal drilling to exert counter pressure on the annular space 1025 to control the downhole pressure exerted by returns in production formation. The drilling rig 1000 can also include a flow meter (not shown) in communication with the return line to measure a return flow rate and record the measurement to the PLC 1070. The flow meter can be single-phase or multi-phase. Alternatively, a flow meter in communication with the PLC 1070 can be at each output of the separators to measure the separate phases independently.
The PLC 1070 can still be in communication with the platform pump to receive a measurement of a flow rate of the drilling fluid injected into the drilling column. In this way, the PLC can balance the mass between drilling fluid 1045f and returns 1045r to monitor the formation of fluid 1090 entering annular space 1025 or drilling fluid 1045f entering formation 1030p. The PLC 1070 can then compare the measurements to values calculated by the PLC 1070. If nitrogen is being used as part of the drilling fluid, then the nitrogen flow rate can be communicated to the PLC 1070 via a flow meter in communication with the nitrogen production or a flow rate measured by a booster compressor in communication with the nitrogen production unit. If the values exceed the limit values, the PLC 1070 can take corrective measures to adjust the choke 1065. A first pressure sensor (not shown) can be arranged in the vertical mud distribution pipe, a second pressure sensor (not shown) it can be arranged between the output of the RCD 1060o and the choke 1065 and a third pressure sensor (not shown) can be arranged in the return line downstream of the choke 1065. The pressure sensors may be in data communication with the PLC.
Drill column 1050 may include drill bit 1050 disposed on a longitudinal end thereof, one of the bypass tools discussed above (represented by 1050s), and a drill pipe column 1050p. Alternatively, casing, casing, or spiral tubing can be used instead of 1050p drill pipes. The 1050 drill string may also include a downhole equipment (BHA) (not shown), which may include the 1050b drill bit, drill collars, a mud engine, a sub-tip, sensors for measuring during drilling (MWD) , sensors for recording during drilling (LWD) and / or a float valve (to prevent fluid flow from the annular space). The mud engine can be of a positive displacement type (ie, a Moineau engine) or of a turbomachinery type (ie, a mud turbine). The drill string 1050 can also include float valves distributed along it, such as one every 30 supports or 10 reserve stocks, to maintain back pressure on the returns, while adding supports to it. The perforation column 1050 may also include one or more centralizers 1050C (Figure 14D) spaced along it at regular intervals. The 1050 drill bit can be rotated from the surface by the rotary table or a top and / or bottom unit by the mud motor. If a subtorto and mud engine are included in the BHA, slide drilling can be performed only by the mud engine rotating the rotary or linear drill bit and can be performed by slowly rotating the surface drill column while the mud engine rotates the drill bit. Alternatively, if spiral tubing is used instead of the drill pipe, the BHA can include a guide to switch between rotary or slide drilling. If the 1050 drill string is a casing or liner, the casing or seal liner can be suspended in the well bore and cemented after drilling.
The drill string 1050 can be operated to drill through the casing shoe 1015s and then extend the well hole 1005 through the drill in the 1030p production formation. A drilling fluid density 1045f can be less than or substantially less than a pore pressure gradient of the 1030p production formation. A free (unrestricted) flow equivalent to the circulation density (ECD) of the 1045r returns can also be less than or substantially less than the pore pressure gradient. During drilling, the variable choke 1065 can be controlled by the PLC 1070 to keep the ECD to be equal (administered pressure) or lower (underbalanced) to the pore pressure gradient of the 1030p production formation. If, during drilling the production formation, drill bit 1050b needs to be replaced after the total depth is reached, drill column 1050 can be removed from well hole 1005. Drill column 1050 can be raised until the drill 1050b is above the hinge 1020 and the bypass tool is aligned with the power sub. The 1050s bypass tool can then be operated to fit the power sub (or one of the power subs) to close the 1020 hinge. Alternatively, as discussed above, the 1050s bypass tool can be omitted for some modalities (ie, valve 500) and an instruction signal can be sent to valve 1020.
Drill column 1050 can then be raised further until the BHA / drill bit is close to well head 1040. An upper portion of well bore 1005 (above hinge 1020) can then be vented at atmospheric pressure. The 1045r returns can also be displaced from the upper portion of the well hole using air or nitrogen. The RCD 1060 can then be opened or removed, so that the drill bit / BHA 1050b can be removed from well 1005. If the full depth is not reached, the drill bit 1050b can be replaced and the drill column 1050 can be be reinstalled in the well hole. The annular space 1025 can be filled with drilling fluid 1045f, the pressure at the top of the well hole 1005 can be equaled with the pressure at the bottom of the well hole 1005. The bypass tool 1050s can be operated to fit the sub and open the hinge 1020. Drilling can then start again. In this way, the production formation 1030p can remain alive during the maneuver due to the isolation of the upper portion of the well hole by the closed hinge 1020, thus avoiding the need to eliminate the production formation 1030p.
Once the drilling has reached full depth, the 1050 drill string can be retrieved to the drill rig as discussed above. A casing column, such as a 10751 expandable seal casing column, can then be implanted in well bore 1005 using a 1075 working column. The 1075 working column can include a 1075e expander, the 1050s bypass tool, a seal 1075p and the 1050p drill pipe column. The 10751 expandable sealing coating can be constructed from one or more layers, as well as three layers. The three layers may include a cracked structural base pipe, a layer of filter material, and an outer cover. Both the base pipe and the external cover can be configured to allow the flow of hydrocarbons through perforations formed inside. The filter material can be kept between the base pipe and the outer cover and can serve to filter sand and other particles so that they do not enter the expandable sealing coating 10751. The sealing coating column 10751 and the working column 1050s can be implanted into the working well bore using the 1020 isolation valve, as discussed above for the 1050 drill string.
Once deployed, expander 1075e can be operated to expand seal liner 10751 to fit with the lower portion of the well that passes through the 1030p production formation. Once the seal liner 10751 has been expanded, seal 1070s can be placed against seal liner 1015. Seal 1075p may include a removable plug assembly located therein, isolating the production formation 1030p from the upper portion of well 1005. The seal housing can have a projection to receive the 1080 production tube column. Once the seal is defined, the 1075e expander, the 1050s bypass tool, and the drill rig can be retrieved from the well using the insulation 1020 as discussed above for drill string 1050.
Alternatively, a conventional solid sealant coating can be implanted and cemented into the 1030p production formation and then drilled to provide fluid communication. Alternatively, a perforated sealing coating (and / or sand screen) and gravel can be installed or the 1030p production formation can be left exposed (also known as bare feet)
The RCD 1060 BOP 1055 can be removed from the well hole 1040. The production tree 1085 (also known as Christmas tree) can then be installed in the well hole 1040. The production tree 1085 can include a body 1085b, a device a 1085h pipe suspension, a 1085v production choke, and a 1085c cover and / or plug. Alternatively, production tree 1085 can be installed after production pipe 1080 is hung from wellhead 1040. Production pipe 1080 can then be deployed and can be lodged in the sealing body. The sealing plug can then be removed, such as by means of a fixed net or a single fiber wire (slickline) and a lubricator. The 1085c tree cover and / or plug can then be installed. The hydrocarbons 1090 produced from the 1030p formation can enter a cavity in the seal liner 10751, pass through the cavity of the liner, and enter a cavity in the production pipe for transport to the surface 1035.
Figure 12A illustrates a portion of a sub power 1100 for use with the insulation equipment in a recessed position, according to another embodiment of the present invention. Figure 12B illustrates a portion of the power sub in an extended position.
Power sub 1100 may include a tubular housing 1105, a tubular mandrel 1110, a jacket 1125, an actuator 1150, a piston (not shown, see 315), and a controller (not shown). Housing 1105 may have couplings (not shown), formed at each longitudinal end thereof for connection to other components of the coating / coating column. The couplings can be threaded, such as a box and a pin. Housing 1105 may have a central longitudinal cavity therethrough. Although shown as a part, housing 1105 can include two or more sections to facilitate fabrication and assembly, each section connected to each other, for example secured with threaded connections. The power sub 1100 can be operated by an 1175 bypass tool mounted as part of the drill string, instead of a part of the 1175 bypass tool.
Chuck 1110 can be arranged inside housing 1105, connected longitudinally to it and rotatable with respect to it. Chuck 1110 may include an upper drive portion 1110 c, f, I and a jacket portion 1110 connected by a base portion 1110b. The drive portion may include a plurality of split pincer fingers 1110f extending longitudinally from the (solid) base 1110b. The fingers may have 1110 l handles formed at a distal end of the base 1110b. The fingers 1110f can be operated between the retracted position and the extended position by interacting with the jacket 1125. The jacket 1125 may include an upper portion of the jacket 1125u and a lower jacket portion 1125 l connected by a projection portion 1125s. The fingers 1110f may include fingers 1110f may further include cams 1110c formed on an outer surface thereof. Each cam 1110c can be received by a follower, such as a slot 1125f, when the fingers are in the stowed position. Each slot 1125f can be formed through a wall of the lower portion of the jacket 1125l and a periphery thereof may have an inclined surface for coupling with a corresponding inclined surface of the cam 1110c during the movement of the fingers 1110f from the retracted position to the extended position . The 1110f fingers can be tilted naturally to the stowed position.
The 11101 handles can fit with the torque profile when the 1100 power sub is in the extended position. The torque profile may include a plurality of ribs 1175r, spaced around and extending along an outer surface of a body 1175b of the 1175 diverter tool, thus rotationally connecting the diverter tool and mandrel 1110, while allowing the relative longitudinal movement between them. The ribs 1175 can be substantially longer than the length of loops 11101 to provide a tolerance coupling and / or to compensate for the 1050 drill string for subsea drilling operations. The mandrel 1110 may also have a helical profile (not shown) formed on a portion of an outer surface of the jacket portion 1110s.
The actuator 1150 may include an antenna 1126, an electronics package 1125, a battery 1131, a case 1151, a lock 1152, 1153, a latch 1154, a proximity sensor 1155 (or position sensor, see 755) and a polarizing member, such as a helical spring 1130. The antenna 1126 and the packaging of the electronic equipment 1125 may be similar to the antenna 226i and the packaging of the electronic equipment 1125, respectively. Housing 1105 may also have upper and lower projections 1107u (not shown) formed on an interior surface thereof. Chamber 1107 can be defined longitudinally between an upper seal, arranged between housing 1105 and case 1151 in the vicinity of the upper projection 1107u and the lower seals disposed between housing 1105 and drive 1110 and between the mandrel and the drive in the vicinity of bottom projection.
The lubricant can be disposed in an isolated portion of chamber 1107. A compensating piston (not shown) can be disposed in housing 1105 to compensate for the displacement of the lubricant, due to the movement of the drive and / or the jacket 1125. The compensating piston can serve also to equalize the pressure of the lubricant (or increase slightly) with pressure in the housing cavity.
The case 1151 can be tubular and have upper projections 1151u and lower 11511 formed on an internal surface of the same. Case 1151 can be connected longitudinally to housing 1105. Spring 1130 can be arranged in a sub-chamber against a bottom of the bottom projection 11511 and a top of the projection 1125s, thus polarizing the jacket 1125 towards a lower position where the fingers 1110 f are extended. The jacket 1125 can be selectively contained in an upper position (where the fingers 1110f are indented) by the latch 1154 and the lock 1152, 1153. The latch can be a clamp 1154 connected to the case 1151 as it is being secured. The 1154 clamp may include a base ring and two or more radially split fingers. The upper jacket portion 1125u may have a profile 1125g formed on an external surface thereof to receive the clamp 1154, thus longitudinally connecting the jacket 1125 and the case 1151. The clamp 1154 can be naturally polarized to fit with the 1125g profile. The polarization of the spring may be sufficient to direct the clamp 1154 of the profile 1125g.
The closure may include a linear actuator 1152, such as a linear motor, and a jacket 1153 movable longitudinally in relation to the housing by the linear actuator between a locked position and an unlocked position. The 1153 jacket can fit an external surface of the pincer fingers in the locked position, thus preventing the fingers from moving radially out of the 1125g profile. The 1153 jacket can be removed from the fingers in the unlocked position, thus allowing the fingers of the clamp to move out of the 1125g profile. The 1152 linear actuator can be attached to the 1151 case and be in electrical communication with the packaging of the 1125 electronic equipment through the internal cables. The proximity sensor 1155 can be a contact switch or Hall sensor and operable by magnet to detect proximity / contact between the top of the jacket 1125 and the projection 1151u and can be in electrical communication with the microprocessor through cables. The microprocessor can use the proximity sensor 1155 to determine when the 1125g profile is aligned with to extend the 1153 closure jacket and lock the clamp fingers in the profile. The microprocessor can also use the proximity sensor to check whether the valve has opened or closed. The antenna 1126 can be connected or attached to an internal surface of the case 1151 and in electromagnetic communication with the housing cavity. The 1126 antenna can be in electrical communication with the microprocessor via cables.
The piston can be tubular and have a projection arranged in a piston chamber (not shown, see 306) formed in housing 1105. Housing 1105 can also have upper and lower projections (not shown, see 306u, l) formed on a surface inside them. The piston chamber can be radially defined between a piston and a housing 1105 and longitudinally between an upper seal (not shown) disposed between housing 1105 and the piston near the upper projection and a lower seal (not shown) disposed between housing 1105 and the piston near the bottom projection. A piston seal (not shown) can also be arranged between the piston projection and the 1105 housing. Hydraulic fluid can be arranged in the piston chamber. Each end of the piston chamber can be in fluid communication with a respective hydraulic coupling (not shown) through a respective hydraulic passage (not shown, see 309p) formed longitudinally through a wall of the housing 1105.
The drive can be arranged between mandrel 1110 and housing 1105 and movable longitudinally with respect to housing 1105 between an upper and a lower position. The drive can be rotatably connected to housing 1105 and movable longitudinally in relation to it. The drive can interact with the mandrel 1110 by having a helical profile formed on an internal surface of the same coupled with the helical mandrel profile. The drive can be connected longitudinally to the piston or integrally formed with it. The helical profiles can allow the drive to move longitudinally without turning while the mandrel 1110 is turned by the 1175 bypass tool without turning. The drive can also interact with the liner 1125. As the liner 1125 is moved from the upper to the lower position by the 1130 spring, the lower part of the liner can engage a top of the drive, thereby stopping the movement of the liner in the lower position.
Two 1100 power subs (only one shown) can be connected hydraulically to isolation valve 50 in a three-way configuration such that each of the sub power pistons are in opposite positions and the operation of one of the power subs operates at isolation valve 50 between open and closed positions and alternate the other 1100 energy sub. The three-way configuration can allow each 1100 energy sub to be operated in only one direction of rotation and each 1100 energy sub to open or close the isolation valve 50. respective hydraulic couplings of each 1100 energy sub and isolation valve 50 can be connected by a drive, such as from production pipes (not shown).
The bypass tool 1175 may include an opening or closing label 1175t, similar to opening or closing labels 601o, and incorporated in an outer surface of the body 1175b. The built-in label 1175c may be located near an end of the ribs 1175r. The 1175 bypass tool may also include a 1175p protector formed in proximity to the 1175t tag at an opposite end of the tool, thus covering the tag to prevent damage to it. The drill column 1150 may also include a second bypass tool (not shown) similar or identical to the bypass tool 1100 except for the inclusion of the other of the opening and closing tag. Alternatively, one of the tags 250a, p, w can be pumped through the drill string 1050 instead of using the built-in tags 1175t and the same bypass tool can be used to operate both power subs.
In operation, once the actuator 1150 receives the instruction signal from the tag 1175c, the microprocessor can operate the linear actuator to retract the jacket from the clasp 1153, thus releasing the jacket 1125. The spring 1130 can push the jacket 1125 and extend the fingers 1110f, thus fitting the handles 11101 with the ribs 1125r. The drill column 1050 can be rotated, thus rotating the 1175 maintenance tool. If the handles 11101 are misaligned, the handles can engage with the ribs 1175r when the rotation of the 1175 bypass tool begins. Rotation of the deviation tool 1175 can lead to rotation of the mandrel 1110. Rotation of the mandrel 1110 can drive the drive longitudinally upwards due to the interaction of the helical profiles. The drive can push the piston longitudinally to the upper position, thereby pumping hydraulic fluid to the isolation valve 50 and opening and closing the valve.
As the drive 1125 moves upward, the drive may push the jacket 1125 towards the upper projection 1151u until the profile of the jacket 1125g engages the latch 1154 and the cams 1110c engage the slots 1125f, thereby retracting the fingers 1110f. The retraction of the fingers 1110f can ensure that the continuous rotation of the diversion tool 1175 does not damage the power sub 1110 and the isolation valve 50. The microprocessor can then detect the fit of the profile 1125g with the latch 1154 and fit the lock 1154.
Since the other sub-power is operated by the respective maintenance tool, the fluid returning from the isolation valve 50 can push the piston down, thus longitudinally pulling the drive to the lowest position. The chuck 1110 can counter-rotate freely to facilitate movement. The 1100 power sub can be readjusted for future operation.
In addition, any of the 600, 650, 575 chargers can be used to charge the 1131 battery and a capacitor can be used instead of or in addition to the battery as discussed above. Alternatively, the energy sub 110 may include a protective jacket covering the fingers 1110f in the stowed position and the retracting fingers extending so as not to obstruct the extension of the fingers. Alternatively, serrated wedges and a cone, drag blocks, clamps, or radial pistons can be used instead of the 1110f fingers. Alternatively, fingers 1110f can longitudinally connect mandrel 1110 and maintenance tool 1175 and the power sub can be operated by the longitudinal movement of the bypass tool.
Figure 13A is a cross section of a bypass tool 101 to drive the isolation set between positions, according to another embodiment of the present invention. The bypass tool 101 can be similar to that of the bypass tool 100, except for the inclusion of a manual command. The hand control may include a piston 111 (instead of piston 110) and a hydraulic lock 151 (instead of hydraulic lock 150). Piston 111 may be similar to that of piston 110 except that a seat 111b may be formed on its internal surface to receive a locking member, such as a ball 170. Lock 151 may be similar to lock 150 except that a rupture member, such as a rupture disc 164, can replace check valve 154. Alternatively, a pressure relief valve can be used instead of the rupture disc. In the event that the telemetry sub 200 and / or the hydraulic lock 151 is damaged during drilling, the ball 170 can be implanted, such as by pumping, through the drill column until the ball stops on the 111b seat. Pumping can continue, thereby exerting fluid force on ball 170 and seat 111b until the pressure in the lower chamber is equal to or exceeds the burst pressure of disc 164. Once ruptured, the pressure in the lower chamber can be relieved by fluid flowing through the opening passage 159c to the lower chamber, thus also releasing piston 111 to move down and extending the drives to fit with any of the energy subs discussed above. The isolation valve can be closed and the drill string retrieved to the platform.
Figures 13B and 13C illustrate a portion of an isolation valve 501 in the closed position, according to another embodiment of the present invention. Isolation valve 501 can be similar to isolation valve 500 except that it includes a manual control. The hand control can include an actuator 551 (instead of actuator 550) and a biasing member, such as a helical spring 513. The spring 513 can be arranged against a top of the seal casing section 505d and a projection of the flow tube 515 thus diverting the flow tube away from the hinge 520. The 551pump actuator can generate enough pressure to overcome the spring bias when opening the 501 valve. A profile 515 can be formed on an internal surface of the flow tube 515. The actuator 515 can be similar to that of actuator 550 except that a rupture member, such as a rupture disk 564, can be added. Alternatively, a pressure relief valve can be used instead of the rupture disc. The rupture disk 564 can be in fluid communication with the hydraulic passage 553u, l. A duplicate bypass tool (not shown) can be mounted as part of the drill string.
In the event that the 551 actuator is damaged during drilling, the deflection tool can be extended to fit the 515p profile. The drill string can be pulled up onto the drill rig, thereby pulling the flow tube 515. The pressure may increase in passage 5531 until the pressure is equal to or exceeds the burst pressure in disk 564. Once ruptured, the pressure in the upper passage can be relieved by the fluid flowing through the rupture disc 564 to the lower passage, thus also releasing the flow tube 515 to move upwards and allowing the hinge spring 521 to close the hinge 520. the drill column can then be retrieved to the platform.
While the foregoing is directed to the embodiments of the present invention, other additional embodiments of the invention can be designed without departing from the basic scope of the same, and the scope of the same is determined by the following claims.

权利要求:
Claims (21)
[0001]
1. Method of drilling a well hole (1005) characterized by the fact that it comprises: drilling a well hole (1005) through a formation when injecting a drilling fluid (1045f) through a drilling column (1050) and rotating a drill bit (1050b), in which the drill column (1050) comprises a bypass tool (1050s), an antenna in communication with the bypass tool (1050s) and located adjacent to a hole in the drill column, a microprocessor in communication with the antenna and the bypass tool, and the drill bit (1050b); retrieving the drilling column (1050) from the well hole (1005) through a housing column (1015) until the bypass tool (1050s) reaches an actuator, where the housing column (1015) comprises a valve insulation (50) in an open position and the actuator; pump a wireless instruction tag, WIT, through the hole in the drill string into the antenna, thus sending a wireless instruction signal to the antenna, where the microprocessor makes the bypass tool (1050s) fit the actuator in response to the receipt the instruction signal by the antenna; and operating the actuator using the fitted diversion tool (1050s), thus closing the isolation valve (50) and isolating the formation (1030p) from an upper portion of the well hole (1005).
[0002]
2. Method according to claim 1, characterized by the fact that the actuator is operated by moving the drilling column (1050) longitudinally.
[0003]
3. Method, according to claim 1, characterized by the fact that the actuator is operated by rotating the drill string (1050).
[0004]
4. Method, according to claim 1, characterized by the fact that it also comprises detecting a position of the actuator or isolation valve (50) after operating the actuator.
[0005]
5. Method, according to claim 4, characterized by the fact that: the actuator comprises a wireless identification tag, WIT, incorporated in it, and the position is detected using the wireless identification tag, WIT.
[0006]
6. Method according to claim 4, characterized by the fact that: the isolation valve (50) comprises a wireless identification tag dispenser, WIT, the tag dispenser is operable to release a WIT encoded with the position of the valve (50) in response to the closing of the valve (50), and the position is detected by reading the dispensed label.
[0007]
7. Method according to claim 4, characterized by the fact that: the isolation valve (50) comprises a hinge (1020), and the position of the hinge (1020) is detected.
[0008]
8. Method, according to claim 7, characterized by the fact that it also comprises: communicating the detected position to the deviation tool (1050s); e send the detected position to the wireless surface.
[0009]
9. Method according to claim 1, characterized by the fact that the instruction signal is sent from a drilling probe (1000).
[0010]
10. Method according to claim 1, characterized by the fact that the instruction signal is sent from a housing column (1015).
[0011]
11. Method of drilling a well hole (1005), characterized by the fact that it comprises: drilling the well hole (1005) through a formation by the injection of drilling fluid (1045f) through a casing column (1015) and rotate a drill bit (1050b); retrieving the drill column (1050) from the well hole (1005) through a casing column (1015) until the drill bit (1050b) is above a closing member, the casing column (1015) comprises the closing member in an open position and an actuator having an antenna; pump a wireless closure identification tag, WIT, through the drill string and over an annular space between the drill string and the casing string, where: the lock WIT passes in the antenna range, and the actuator closes the closing member in response to communication with the closing WIT, thereby isolating the formation of an upper portion of the well hole; removing the drill column from the well hole; implanting a working column or the drill column in the hole pumping an opening WIT through the drilling column or the working column and up to the annular space, where: the opening WIT passes into the antenna range and the actuator opens the closing member in response to communication with the Opening WIT.
[0012]
12. Method according to claim 11, characterized by the fact that: the drill string (1050) comprises a charger, and the method further comprises charging a battery or capacitor of the actuator.
[0013]
13. Method according to claim 12, characterized by the fact that the battery or capacitor is charged wirelessly.
[0014]
14. Method according to claim 12, characterized by the fact that: the charger comprises an electromagnet, and the battery or capacitor is charged by moving the charger longitudinally relative to the isolation valve (50).
[0015]
15. Method according to claim 11, characterized by the fact that: the isolation valve (50) comprises a thermoelectric generator, and the method further comprises charging a battery or capacitor of the actuator when circulating the drilling fluid (1045f ) through the borehole (1005).
[0016]
16. Method according to claim 11, characterized by the fact that it also comprises detecting a position of the actuator or closing member after the closing member is closed.
[0017]
17. Method according to claim 16, characterized by the fact that the position of the closing member is detected.
[0018]
18. Method according to claim 16, characterized by the fact that: a wireless ID tag dispenser, WIT is connected to the closing member, the tag dispenser is operable to release a WIT encoded with the valve position (50) in response to the closing of the closing member, and the position is detected by reading the dispensed label.
[0019]
19. Method according to claim 16, characterized by the fact that it also comprises sending the detected position to the wireless surface.
[0020]
20. Method according to claim 11, characterized by the fact that: the housing column (1015) comprises a hydraulic pump in fluid communication with a casing hole, an accumulator and an operable piston coupled to the closing member, the The pump charges the accumulator in response to pressure fluctuations in the liner perforation, and the actuator selectively provides fluid communication between the accumulator and the piston.
[0021]
21. Method of drilling a well hole (1005) characterized by the fact that it comprises: drilling a well hole (1005) through a formation when injecting a drilling fluid (1045f) through a drilling column (1050) and rotating a drill bit (1050b), in which the drill string (1050) comprises a wireless identification tag, WITs, opener and locker inserted in a lower portion of the drill string (1050), in which the opener WIT is located on the closing WIT; and recovering the drilling column (1050) from the well hole (1005) through a housing column (1015) until a drill bit (1050b) is above a closing member where: the housing column (1015) comprises the closing member in an open position and an actuator with a microprocessor, a position sensor and an antenna for communication with the WITs, the WITs are spaced by a sufficient distance so that the tags are not simultaneously within reach of the antenna, the The microprocessor reads the opening WIT first and ignores the opening WIT based on the current open position of the closing member, and the microprocessor then reads the closing WIT and closes the closing member, thereby isolating the formation of an upper portion of the opening hole. well (1005).

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法律状态:
2018-12-26| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|

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2019-10-01| B06U| Preliminary requirement: requests with searches performed by other patent offices: procedure suspended [chapter 6.21 patent gazette]|

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2020-08-04| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|

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2020-11-17| B25A| Requested transfer of rights approved|Owner name: WEATHERFORD/LAMB, INC. (US) |

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2020-12-15| B16A| Patent or certificate of addition of invention granted [chapter 16.1 patent gazette]|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 20/09/2011, OBSERVADAS AS CONDICOES LEGAIS. |

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2021-06-01| B16C| Correction of notification of the grant [chapter 16.3 patent gazette]|Free format text: REFERENTE AO DESPACHO 16.1 PUBLICADO NA RPI 2606, QUANTO AO NOME DO TITULAR |

优先权:

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申请号 | 申请日 | 专利标题

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US38449310P| true| 2010-09-20|2010-09-20|

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US61/384,493|2010-09-20|

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US13/227,847|2011-09-08|

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PCT/US2011/052383|WO2012040220A2|2010-09-20|2011-09-20|Signal operated isolation valve|

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