Patent application number | Description | Published |
20080230271 | Downhole abrading tools having fusible material and uses therefor - A downhole abrading tool has a body with a first end for connection to a drill string, a cutting end, a drilling fluid passageway, and a fusible material disposed within the body. The fusible material is capable of igniting and combusting in response to a selected temperature increase due to excessive wear on the cutting end. Combustion of the fusible material provides an indication to an operator of the downhole abrading tool of the excessive wear on the cutting end of the downhole abrading tool so that the downhole abrading tool can be removed from the well and replaced. The indication to the operator of the downhole abrading tool can be a temperature change or a pressure change in a drilling fluid flowing through the drilling fluid passageway. | 09-25-2008 |
20080308284 | ELASTOMERIC ELEMENT INSTALLATION TOOL AND METHOD - Disclosed herein is a method of installing an elastomeric element onto a tubular. The method includes, positioning the elastomeric element onto a radially expandable member, radially expanding the radially expandable member and the elastomeric element installed thereon, positioning a tubular coaxially with the radially expandable member, and axially urging the elastomeric element off the radially expandable member thereby allowing the elastomeric element to be positioned coaxially about an outer perimetrical surface of the tubular. | 12-18-2008 |
20090056934 | Interventionless multi-position frac tool - Fracturing tools for use in oil and gas wells are disclosed. The fracturing tools have a run-in position and two operational positions. A sleeve disposed in the bore of the fracturing tool comprises a sleeve port alignable with a first port in the housing of the frac tool, i.e., the first operational position, during fracturing operations. A second port having a restriction member is disposed in the housing and is closed by the sleeve during fracturing operations. After fracturing operations are completed, a return member in the frac tool moves the sleeve from the first operational position to a second operational position for production operations. In this second operational position, the first port is closed and the sleeve port is aligned with the second port. Movement of the sleeve from the first operational position to the second operational position is performed without the need for an additional well intervention step. | 03-05-2009 |
20090095470 | Downhole abrading tools having excessive wear indicator - A downhole abrading tool having a body with a first end for connection to a drill string, a cutting end, a drilling fluid passageway, a restrictor disposed within drilling fluid passageway, and an indicator chamber is disclosed. Upon exposure of the indicator chamber to a well environment due to excessive wear on the cutting end, the restrictor is actuated. Actuation of the restrictor restricts the flow of drilling fluid from the drilling fluid passageway into the well environment. The restriction of flow of drilling fluid from the drilling fluid passageway causes a pressure increase in the drilling fluid flowing through the well that can detected by an operator of the downhole abrading tool. The pressure increase provides an indication to the operator of excessive wear on the cutting end of the downhole abrading tool so that the downhole abrading tool can be removed from the well and replaced. | 04-16-2009 |
20090095487 | FLOW RESTRICTION DEVICE - An inflow control device may include flow control elements along a flow path. The flow control elements may change the inertial direction of the fluid flowing in the flow path. The change in inertial direction occurs at junctures along the flow path. The flow control elements may also be configured to form segmented pressure drops across the flow path. The segmented pressure drops may include a first pressure drop segment and a second pressure drop segment that is different from the first pressure drop segment. The pressure drop segments may be generated by a passage, an orifice or a slot. In embodiments, the plurality of flow control elements may separate the fluid into at least two flow paths. The flow control elements may also be configured to cause an increase in a pressure drop in the flow path as a concentration of water increases in the fluid. | 04-16-2009 |
20090130938 | SWELLABLE MATERIAL AND METHOD - An element includes a swellable material; and a fibrous material embedded in the swellable material and method. | 05-21-2009 |
20090139729 | DOWNHOLE TOOL WITH CAPILLARY BIASING SYSTEM - A downhole tool and capillary biasing system includes a housing; an intrusion fluid contained within a portion of the housing; a capillary biasing member in fluid contact with the intrusion fluid; and a pressure application configuration capable of pressurizing the intrusion fluid within the housing and method. | 06-04-2009 |
20090146835 | WIRELESS COMMUNICATION FOR DOWNHOLE TOOLS AND METHOD - A system for setting a tool in a downhole environment includes a communicator configured to broadcast a signal; a downhole tool configured to receive the signal from the communicator and execute on an instruction conveyed by the signal, a radio wave inhibiting structure being interposed between the communicator and the downhole tool and method. | 06-11-2009 |
20090229838 | Large Bore Packer and Methods of Setting Same - Devices and methods for setting a packer inside a wellbore with little appreciable reduction of the useable area of the wellbore. The outer casing or liner of the wellbore contains one or more integrated casing coupler joints having an increased diameter chamber portion. A large bore packing element is carried within the increased diameter chamber portion. The packing element may be selectively actuated to form a seal against an interior tubular member. Because the packing element is located within the chamber portion of the casing coupler, the packer may be set while saving useable cross-sectional area within the casing. | 09-17-2009 |
20090308590 | FISHING OVERSHOT TOOL - A fishing tool gripper head including at least one moveable jaw of a set of jaws, a motivator including one or more of an SMA, SMP, or EAP material in operable communication with the at least one moveable jaw and a method for engaging a fish in a wellbore. | 12-17-2009 |
20090321076 | Completion Method with Telescoping Perforation & Fracturing Tool - An apparatus and method for perforating a liner, fracturing a formation, and injection or producing fluid, all in one trip with a single tool. The tool has a plurality of outwardly telescoping elements ( | 12-31-2009 |
20100147509 | Large bore packer and methods of setting same - Devices and methods for setting a packer inside a wellbore with little appreciable reduction of the useable area of the wellbore. The outer casing or liner of the wellbore contains one or more integrated casing coupler joints having an increased diameter chamber portion. A large bore packing element is carried within the increased diameter chamber portion. The packing element may be selectively actuated to form a seal against an interior tubular member. Because the packing element is located within the chamber portion of the casing coupler, the packer may be set while saving useable cross-sectional area within the casing. | 06-17-2010 |
20100155083 | OPEN-HOLE ANCHOR FOR WHIPSTOCK SYSTEM - An anchoring system including a housing; a chamber defined by the housing; and one or more telescopic assemblies disposed in contact with a wall of the housing and responsive to pressure within the chamber and a method for anchoring a tool in a wellbore. | 06-24-2010 |
20100224359 | Subterranean Screen with Varying Resistance to Flow - A screen section is made with variable resistance to flow in the screen material to balance the flow along the screen length. In one variation different discrete zones have screens configured for different percentages of open area while all have the same particle filtration capability. In another variation discrete portions have differing amounts of overlapping screen portions so as to balance flow without affecting the particle size screened. The cross-sectional shape of a wire wrap underlayment for the screen is made closer to trapezoidal to decrease the angle of opening for the incoming flow paths toward the base pipe. In this manner flow resistance is reduced and flow is increased due to reduced turbulence. | 09-09-2010 |
20100258289 | Slickline Conveyed Tubular Cutter System - A tubular cutter is run in on slickline. It features onboard power to selectively actuate an anchor and to initiate a tubular cutting operation with a cutter that is extendable and rotatable on its axis and the axis of the tool that carries an on board power supply. | 10-14-2010 |
20100258293 | Slickline Conveyed Shifting Tool System - A shifting tool is run on slickline and has an on board power supply. Rotary motion of the motor is converted to linear motion of the shifting tool using a ball screw device. The grip is obtained with longitudinal motion of a grip linkage and an on board jar then can do the shifting. Alternatively a linear motor can be used to extend and retract the grip assembly and shift using the jar tool. Optionally the tool can be anchored and linear motion from the on board power source operating a motor can do the shifting. | 10-14-2010 |
20100258296 | Slickline Conveyed Debris Management System - A wellbore cleanup tool is run on slickline. It has an onboard power supply and circulation pump. Inlet flow is at the lower end into an inlet pipe that keeps up fluid velocity. The inlet pipe opens to a surrounding annular volume for sand containment and the fluid continues through a screen and into the pump for eventual exhaust back into the water in the wellbore. A modular structure is envisioned to add debris carrying capacity. Various ways to energize the device are possible. Other tools run on slickline are described such as a cutter, a scraper and a shifting tool. | 10-14-2010 |
20100258298 | Slickline Conveyed Tubular Scraper System - A downhole tubular scraper is run in on slickline with an on board power supply. It features counter-rotating scrapers without an anchor in one embodiment or an anchor with single rotating scrapers. The scraper is selectively operated to conserve power in the power supply. A drive system uses a single driver to obtain counter-rotating motion in the scrapers. | 10-14-2010 |
20100263871 | Open Hole Frac System - A fracturing operation is done in open hole without annular space isolation. The annular space is spanned by telescoping members that are located behind isolation valves. A given bank of telescoping members can be uncovered and the telescoping members extended to span the annular space and engage the formation in a sealing manner. Pressurized fracturing fluid can be pumped through the telescoped passages and the portion of the desired formation fractured. In a proper formation, cementing is not needed to maintain wellbore integrity. The telescoping members can optionally have screens. Normally, the nature of the formation is such that gravel packing is also not required. A production string can be inserted into the string with the telescoping devices and the formation portions of interest can be produced through the selectively exposed telescoping members. | 10-21-2010 |
20100282338 | Selectively movable seat arrangement and method - Disclosed herein is a selectively movable seat arrangement. The seat arrangement includes, one or more seat members movable between a passable position where a member is passable therethrough and an impassable position where the member is prevented from passing therethrough, and a counter in operable communication with the one or more seat members, the counter capable of allowing movement of the one or more seat members to the passable position to allow passage of a member a selected number of times and then to the impassable position thereby preventing passage of another such member for a period of time. | 11-11-2010 |
20100282469 | Fracturing with Telescoping Members and Sealing the Annular Space - A fracturing operation is done in open hole. The annular space is spanned by telescoping members that are located behind isolation valves. A given bank of telescoping members can be uncovered and the telescoping members extended to span the annular space and engage the formation in a sealing manner. Pressurized fracturing fluid can be pumped through the telescoped passages and the portion of the desired formation fractured. In a proper formation, cementing is not needed to maintain wellbore integrity. In formations that need annular space isolation, the string in a preferred embodiment can have an external material that grows to seal the annular space in lieu of a traditional cementing operation. | 11-11-2010 |
20100294370 | FLOW-ACTUATED ACTUATOR AND METHOD - Disclosed herein is a flow-actuated actuator. The actuator includes, a tubular with a flow passageway having a first flow area, and at least one movable member in operable communication with the tubular. The at least one movable member is movable relative to the tubular between at least a first position and a second position, the at least one movable member configured to form a second flow area that is smaller than the first flow area when in the second position, the flow-actuated actuator is configured to move a separate member in response to fluid flow therethrough. | 11-25-2010 |
20100294508 | FLOW-ACTUATED ACTUATOR AND METHOD - Disclosed herein is a flow-actuated actuator. The actuator includes, a tubular movable relative to a structure within which the tubular is positionable, and a plurality of full bore flow-resisting elements disposed at the tubular, the plurality of full bore flow-resisting elements having a greater resistance to fluid flow therethrough than any one of the plurality of full bore flow-resisting elements has alone. | 11-25-2010 |
20100294509 | FLOW-ACTUATED ACTUATOR AND METHOD - Disclosed herein is a downhole flow-actuated actuator. The actuator includes, a first tubular, a second tubular longitudinally movably disposed within the first tubular and movable in response to fluid flow therethrough, the second tubular having a full bore therethrough, and a movable member movably attached to the second tubular and movable with the second tubular relative to the first tubular. The movable member is movable between a first position and a second position, the movable member is unobstructive of the full bore when in the first position and at least partially occluding of the full bore when in the second position, the movable member is movable from the first position to the second position in response to movement of the second tubular. | 11-25-2010 |
20110000681 | Radial Spring Latch Apparatus and Methods for Making and Using Same - New locking connector assemblies and telescoping extension/retraction assemblies are disclosed that operate on the natural spring rate constraints of radial protrusions or radially constrained rings as they interact with engaging members to provide the locking force and permit the connector and extension retraction assemblies to be engage and disengaged or extended and retracted. | 01-06-2011 |
20110005759 | FRACTURING SYSTEM AND METHOD - A telescoping unit for a downhole tool including an innermost portion of the telescoping unit; a block defining a restriction disposed within the innermost portion of the telescoping unit; and an erodable coating on the block to segregate the block from downhole fluids and method. | 01-13-2011 |
20110030968 | TUBULAR ACTUATOR, SYSTEM AND METHOD - A tubular actuating system includes, a tubular, a plurality of same plugs runnable within the tubular, an alterable actuator disposed at the tubular that is alterable in response to passage of a first of the plurality of same plugs run into contact therewith, a second of the plurality of same plugs is seatingly engagable with the alterable actuator run thereagainst when in an altered condition such that pressure built up against the second of the plurality of same plugs causes actuational movement of the alterable actuator, and a flapper seat movably disposed at the alterable actuator between at least a first position defined by the alterable actuator in an unaltered position and a second position defined by the alterable actuator in an altered position. | 02-10-2011 |
20110073320 | TUBULAR ACTUATOR AND METHOD - A tubular actuator includes, a restrictor disposed at a tubular that is engageably receptive to a runnable member run thereagainst as long as pressure remains above a latch pressure, the restrictor configured to allow passage of the runnable member after a delay at pressure equal to or below the latch pressure. | 03-31-2011 |
20110088907 | FLAPPER VALVE AND METHOD - A flapper valve with magnetic field hold open arrangement including a housing; a flapper pivotally mounted to the housing; and a magnet housing slidably mounted to the housing such that a magnetic field generating configuration of the magnet housing is movable between a position where it is capable of holding the flapper in an open position and where it is incapable of holding the flapper in an open position. A method for holding open a flapper of a flapper valve. | 04-21-2011 |
20110088908 | FLAPPER VALVE - A flapper for a downhole valve including a surface configured to substantially geometrically mate with a tubular section within which the flapper is mounted when in an open position. The surface reduces an amount of fluid that can exist between the flapper and a housing member thereby reducing the effect of turbulence on the flapper. The geometrically mating surface may be a hard surface that is configured to mate or may be a softer surface that will self conform. | 04-21-2011 |
20110100647 | Tubular Actuator, System and Method - A tubular actuating system includes a tubular, a plurality of same plugs runnable within the tubular, an actuator disposed within the tubular, and a seatable member disposed at the actuator configured to be respositionable relative to the actuator between an unseated position and a seated position upon passage of at least one of the plurality of same plugs. | 05-05-2011 |
20110108749 | DYNAMIC FLAPPER AND METHOD - An adjustable moment arm flapper including a flapper defining a cavity there within and a moveable mass system disposed within the cavity, a center of mass of the flapper changeable based upon position of the movable mass and a method for dynamically controlling a flapper. | 05-12-2011 |
20110114319 | OPEN HOLE STIMULATION WITH JET TOOL - A fracturing method for preferably open hole uses fluid velocity impinging on the wellbore wall to initiate fractures. Telescoping members that extend using nozzles inside them but come out to a distance from the wellbore wall can be used. Fixed nozzles that do not extend are also another option. The nozzles can be eroded or corroded as the fracturing takes place or they can be made of sufficiently durable materials or have coatings to withstand the erosive effects of high velocity slurries pumped to impinge the wellbore wall to initiate fractures. | 05-19-2011 |
20110132612 | Telescopic Unit with Dissolvable Barrier - A telescopic member includes, at least a central component and a barrier disposed within the central component, the barrier has a selectively tailorable dissolution rate curve and has structural properties enabling the containment of high pressure prior to structural failure of the barrier through dissolution. | 06-09-2011 |
20110168412 | Large Bore Packer and Methods of Setting Same - Devices and methods for setting a packer inside a wellbore with little appreciable reduction of the useable area of the wellbore. The outer casing or liner of the wellbore contains one or more integrated casing coupler joints having an increased diameter chamber portion. A large bore packing element is carried within the increased diameter chamber portion. The packing element may be selectively actuated to form a seal against an interior tubular member. Because the packing element is located within the chamber portion of the casing coupler, the packer may be set while saving useable cross-sectional area within the casing. | 07-14-2011 |
20110214881 | FLOW CONTROL ARRANGEMENT AND METHOD - A flow control arrangement includes a housing defining one or more openings therein; a valve structure alignable and misalignable with the one or more openings in the housing; and one or more plugs, one each in each of the one or more openings, each plug being reducible by one or more of exposure to downhole fluids and applied dissolution fluids and method for carrying out a series of downhole operations. | 09-08-2011 |
20120097265 | RESTRICTION ENGAGING SYSTEM - A restriction engaging system includes, a restriction engager, one or more restrictions, and at least one counter configured to permit or prevent passage of a restriction engager through one of the one or more restrictions. | 04-26-2012 |
20120118573 | Fracturing with Telescoping Members and Sealing the Annular Space - A fracturing operation is done in open hole. The annular space is spanned by telescoping members that are located behind isolation valves. A given bank of telescoping members can be uncovered and the telescoping members extended to span the annular space and engage the formation in a sealing manner. Pressurized fracturing fluid can be pumped through the telescoped passages and the portion of the desired formation fractured. In a proper formation, cementing is not needed to maintain wellbore integrity. In formations that need annular space isolation, the string in a preferred embodiment can have an external material that grows to seal the annular space in lieu of a traditional cementing operation. | 05-17-2012 |
20120298370 | FLOW RESTRICTION DEVICES - An inflow control device may include flow control elements along a flow path. The flow control elements may change the inertial direction of the fluid flowing in the flow path. The change in inertial direction occurs at junctures along the flow path. The flow control elements may also be configured to form segmented pressure drops across the flow path. The segmented pressure drops may include a first pressure drop segment and a second pressure drop segment that is different from the first pressure drop segment. The pressure drop segments may be generated by a passage, an orifice or a slot. In embodiments, the plurality of flow control elements may separate the fluid into at least two flow paths. The flow control elements may also be configured to cause an increase in a pressure drop in the flow path as a concentration of water increases in the fluid. | 11-29-2012 |
20120298371 | FLAPPER VALVE - A flapper for a downhole valve including a surface configured to substantially geometrically mate with a tubular section within which the flapper is mounted when in an open position. The surface reduces an amount of fluid that can exist between the flapper and a housing member thereby reducing the effect of turbulence on the flapper. The geometrically mating surface may be a hard surface that is configured to mate or may be a softer surface that will self conform. | 11-29-2012 |
20130025871 | PLUG COUNTER, FRACING SYSTEM AND METHOD - A plug counter includes a seat receptive of a plug in a first position and capable of passing the plug in a second position. A first sleeve is in operable communication with the seat and is longitudinally movable in response to movement of the seat between the first position and the second position. A second sleeve is in operable communication with at least one of the first sleeve and the seat and is configured to index upon passage of the plug. A key is in operable communication with the seat and is configured to prevent movement of the seat to the second position after a selected number of plugs have passed the seat. A third sleeve is in operable communication with the first sleeve, and a release member is in operable communication with the third sleeve and is configured to move the third sleeve after it is released. | 01-31-2013 |
20130081825 | Apparatus and Methods Utilizing Nonexplosive Energetic Materials for Downhole Applications - In one aspect, a method of method of performing a wellbore operation is disclosed that in one embodiment may include: providing a device that includes a non-explosive energetic material configured to disintegrate when subjected to a selected energy; placing the device at a selected location in the wellbore to perform a selected function; and subjecting the device to the selected energy to disintegrate the device in the wellbore after the device has performed the selected function. In another aspect an apparatus for use in a wellbore is disclosed that in one embodiment may include a device placed in the wellbore at a selected location, wherein the device includes a non-explosive energetic material configured to disintegrate when subjected to a selected energy, and a source of the selected energy configured to subject the device to the selected energy in the wellbore to disintegrate the device. | 04-04-2013 |
20130168091 | JUNK BASKET WITH SELF CLEAN ASSEMBLY AND METHODS OF USING SAME - A downhole tool for removing debris from fluid flowing through the downhole tool comprises a screen member and wiper member, the wiper member having at least one window disposed through the inner and outer wall surfaces of the wiper member. Either the screen member or the wiper member is rotatable such that rotation of the screen member or the wiper member causes debris disposed on the outer wall surface of the screen member to fall-off the screen member. At least one directional port disposed at either the upper end of the screen member or the upper end of the wiper member causes rotation of the screen member or wiper member when fluid flows through the downhole tool. | 07-04-2013 |
20130248249 | One Trip Tubular Cleaning and Drilling Additional Open Hole - A one trip method for cleaning an existing string while performing testing on the string allows in the same trip the drilling of additional wellbore. The cleanup equipment is retracted after the testing is completed so that it will not impede the advancement of the drill bit at the lower end of the string. The cleanup tools are typically extend for run in through the string and they can be collapsed by a technique such as dropping a ball to shift a sleeve to disable the piston assembly that holds the cleanup tools extended and allows them to be retracted using a return spring or other source of potential energy. | 09-26-2013 |
20130299184 | Multi-Cycle Ball Activated Circulation Tool with Flow Blocking Capability - A valve and method of use wherein the valve includes a housing having an axial flowbore defined along its length. A lateral fluid flow port is disposed through the housing. A piston sleeve is disposed within the flowbore and is selectively moveable to block flow through the lateral flow port. The valve can be moved between operating positions wherein flow through the lateral flow port is blocked or allowed and axial flow through the flowbore is blocked or permitted. | 11-14-2013 |
20130341017 | DOWNHOLE DEBRIS REMOVAL TOOL CAPABLE OF PROVIDING A HYDRAULIC BARRIER AND METHODS OF USING SAME - A downhole tool for removing debris from a wellbore comprises a body having a bore, a collection member, and a means for creating a hydraulic barrier within a wellbore annulus. The hydraulic barrier within the wellbore annulus restricts upward movement of a debris laden fluid within the wellbore annulus causing the debris laden fluid to be directed toward the collection member. Thus, the hydraulic barrier facilitates removal of debris from the wellbore. | 12-26-2013 |
20130341027 | DOWNHOLE DEBRIS REMOVAL TOOL AND METHODS OF USING SAME - A downhole tool for removing debris from a wellbore comprises a screen member, an incoming fluid accelerator, and a cavity for capturing debris. The incoming fluid accelerator is disposed above the screen and accelerates the flow of an incoming fluid through the accelerator and into a screen bore. The incoming fluid then exits the bottom of the tool, mixes with wellbore fluid containing debris to form a combination fluid that is transported upward within the wellbore annulus. A pressure differential between the incoming fluid flowing within the screen bore and the wellbore annulus pulls the combination fluid containing the debris into the cavity where the debris is captured. Fluid and/or debris not blocked by the screen flows through the screen into the screen bore to be circulated downward and out of the tool where it can pick up additional debris for capture. | 12-26-2013 |
20140002089 | POWER GENERATING COMMUNICATION DEVICE | 01-02-2014 |
20140182861 | Casing or Liner Barrier with Remote Interventionless Actuation Feature - A tubular string is run into a wellbore with a remotely actuated valve near a lower end adjacent a cementing shoe. The valve is triggered to operate without intervention such as by mud pulses generated at the surface and recognized by a sensor linked to a processor adjacent the valve to trigger the valve to close. Alternative actuation systems are envisioned for the valve that is located near the cementing shoe. | 07-03-2014 |
20140216719 | Junk Basket With Self Clean Assembly And Methods Of Using Same - A downhole tool for removing debris from fluid flowing through the downhole tool comprises a screen member and wiper member, the wiper member having at least one window disposed through the inner and outer wall surfaces of the wiper member. Either the screen member or the wiper member is rotatable such that rotation of the screen member or the wiper member causes debris disposed on the outer wall surface of the screen member to fall-off the screen member. At least one directional port disposed at either the upper end of the screen member or the upper end of the wiper member causes rotation of the screen member or wiper member when fluid flows through the downhole tool. | 08-07-2014 |
20140332205 | Anchor Slip and Seal Locking Mechanism - A test packer is lowered to a set liner hanger in a locked position that prevents the seal and slips from setting during running in. A first ball is dropped to shift a sleeve to release the grip of dogs to a groove on an outer housing. Setting down weight sets the test packer seal and sets the slips. After the casing integrity pressure test is done the test packer is lifted to again position the groove in the outer housing by the dogs. A second ball lands on the same seat now enlarged due to earlier movement and breaks a retainer on a locking sleeve. A spring return or continued downhole motion of the locking sleeve locks the packer in the run in position. Subsequent rotation and circulation can take place as completion fluid is circulated in. A circulation port above the packer can be opened optionally for circulation or reversing above the test packer. | 11-13-2014 |
20140374111 | Downhole Debris Removal Tool and Methods of Using Same - A downhole tool for removing debris from a wellbore comprises a mandrel and a shroud disposed around a portion of the mandrel. The mandrel includes at least one mandrel port in fluid communication with a mandrel bore. The shroud includes a cavity and a shroud port. Debris laden fluid is pulled into the shroud cavity by flowing fluid through the mandrel bore, out the mandrel port, into the shroud cavity, and through the shroud port. The debris-laden fluid is pulled into the shroud cavity due to a pressure differential created by the flow of the fluid through the mandrel port and out of the shroud port. As the debris laden fluid flows into the shroud cavity, the debris is captured within the tool. | 12-25-2014 |
20150027780 | One Trip Drill and Casing Scrape Method and Apparatus - A drilling assembly is tripped in a cased hole to make more open hole. The assembly features retracted scrapers and a closed circulation sub so that the drilling can commence with string pressure delivered to bit nozzles due to the circulation sub being in a closed position. When drilling is done and the bit is to be removed, an object lands on a seat on a sleeve that acts as a piston to break scraper retainers for casing scraping deployment and to open the circulation port. A bypass opens around the seated ball when the sleeve shifts to allow flow around the seated ball for circulation while scraping. Drilling and casing scraping are accomplished in a single trip. | 01-29-2015 |
20150075639 | PLUG COUNTER, FRACING SYSTEM AND METHOD - A valve includes, a tubular having at least one port, a sleeve in operable communication with the tubular configured to uncover the at least one port in response to moving from a first position to a second position, and a seat that is configured to be passed a selected number of times without shifting the sleeve from the first position to the second position and is further configured to be passed one additional time after the selected number of times after shifting the sleeve from the first position to the second position. | 03-19-2015 |