Abstract: A downhole control arrangement for installation in hydrocarbon well and for controlling the operation of a downhole valve arrangement comprises an electrically controlled control valve, wherein the control arrangement comprises a control system and an electric power supply source configured for supplying electric power to the control system. A downhole valve arrangement for controlling the flow of an injection fluid into a production tubing of a hydrocarbon well comprises a control arrangement, and a side pocket mandrel for installation in a production tubing for use in a hydrocarbon well, wherein the side pocket mandrel comprises an interior pocket space and a valve arrangement.

Abstract: Techniques for positioning and setting a barrier within a well string are provided. In one embodiment, a method includes securing a barrier device at a lubricator extension of a lubricator assembly and positioning the lubricator assembly at a wellhead assembly having a wellhead from which a well string is suspended. The method also includes advancing the lubricator extension to advance the barrier device into the well string. The barrier device may be set within the well string to block flow. Additional methods, systems, and devices are also disclosed.

Abstract: A downhole method comprises expanding a patch member. The patch member may be employed in a method of sealing a wall of a bore. The sealing method may comprise: providing the patch member with a sealing material on an exterior surface; running the patch member into the bore in a smaller diameter first configuration; heating the sealing material to render the sealing material flowable; reconfiguring the patch member to a larger diameter second configuration; and hardening the sealing material to provide a seal between the exterior surface of the patch member and an inner surface of the bore.

Abstract: A launch point lift gas velocity control system and method of use, the system operating to maintain minimal well bore lift conditions through injection gas regulation. In one aspect, the minimal wellbore conditions enable a gas-liquid mixture or a downhole tool at a selectable well bore launch point to depart from a targeted launch point lift gas velocity and ascend up the well bore. The launch point may be adjusted to account for variability with time and wellbore location.

Abstract: An assembly includes a cone having a tapered outer surface, a slips assembly positioned at least partially around the tapered outer surface of the cone, and a sealing ring positioned at least partially around the tapered outer surface of the cone. The slips assembly directly engages the sealing ring, such that the slips assembly is configured to transmit a setting force to the sealing ring, which moves the sealing ring on the tapered outer surface of the cone and expands the sealing ring radially outward. The assembly includes an anti-seal ring positioned adjacent to the sealing ring and around the cone. The anti-seal ring is driven along the tapered outer surface of the cone by engagement with the sealing ring.

Abstract: A setting tool for actuating a downhole plug in a wellbore includes a housing, a piston positioned at least partially within the housing wherein the piston defines an internal firing chamber that is in fluid communication with an exhaust port, an expansion chamber positioned between an outer surface of the piston and an inner surface of the housing wherein the exhaust port is configured to convey combustion products along a combustion flowpath extending from the firing chamber and into the expansion chamber, and an exhaust diffuser distinct from the piston and the housing and including an exhaust passage and at least one baffle face, the baffle face configured to redirect the flow of combustion products along the combustion flowpath and channel the flow of combustion products into the exhaust passage.

Abstract: A release mechanism for a mechanically locked wiper plug system is provided. The release mechanism may utilize a shifting sleeve to rotate or pivot a release.sub, thus: disengaging a load shoulder and releasing the plug system, in some embodiments, the plug system may be mechanically locked to a running tool via corresponding slotted load shoulders in the running tool and on a release sub. The release sub may be connected: to an actuation sleeve via shear screws. Furthermore, the actuation sleeve may contain a guide consisting of one or more helical slotted guides which interact with the release sub shear screws.

Abstract: The well system includes a casing and production tubing and a control unit that can receive measurements of temperature and pressure of fluid in the tubing-casing annulus (TCA). A subsurface safety valve (SSSV) connected to the tubing can switch to an open or closed state in response to a change in pressure of the fluid. An expected thermal expansion or contraction of the TCA fluid is calculated based on the received measurements, and the control unit determines, based on the expected thermal expansion or contraction and on a calculated TCA volume, a volume necessary to be added to or released from the TCA to maintain the fluid within an optimal pressure range. The control unit can also receive an indication of an emergency condition and transmit a signal to activate a release valve to release from the TCA a volume of fluid sufficient to cause the SSSV to close.

Abstract: A support ring prevents an elastomer seal from extruding. The support ring is expanded and supports the expanded seal, preventing the elastomer seal failing due to extrusion.

Abstract: A packer for anchoring and sealing to a tubular in a well, the packer including a packer element, an anchoring arrangement, a setting mechanism and a release mechanism. The release mechanism holds a thin-walled section of tubing in the packer in tension using a biasing mechanism. On severing the tubing, the bias releases an engagement mechanism which allows the anchor arrangement and the packing element to move relative to the body and thereby unset the packer. An embodiment of a dual bore packer is described. A method of well isolation is described, with an assembly including the dual bore packer. The primary bore forms the short string and a secondary bore forms the long string. By severing the short string the integrity of the long string is maintained to pull lower devices on the long string and the short string does not require tension below the packer to release.

Abstract: A liner hanger having one: or more enhanced Socking assemblies is provided. The liner hanger includes a liner hanger body, lower slips, upper slips, a packer cone, and a seal that seals an annulus between the liner hanger and an outer casing, The one or more enhanced locking assemblies may include: a packer cone locking assembly that prevents all components of the liner hanger from actuating until it is unlocked; a slips locking assembly that prevents the lower slips from being actuated until it is unlocked; guide rails that prevent. the lower slips and/or the upper slips from being wedged in a radially outward direction during run in; and a floating cone locking assembly that releases the packer cone from being coupled to a spacer of the liner hanger when it is unlocked.

Abstract: Valve systems and methods for inserting into a casing in a downhole environment are provided. A valve system includes a tool mandrel, a check valve assembly, and a setting system. The setting system includes a sealing element, wedges, slips, and a set nut. Each of the wedges and slips includes an inner surface slidable along the outer surface of the tool mandrel. Each wedge includes a primary angled surface and a secondary angled surface. The wedges are located between the slips and the secondary angled surface of one wedge is in contact to the secondary angled surface of the other wedge. Each of the slips includes an outer surface including gripping elements configured to grip an inner surface of the casing. Also, each of the slips includes an angled side surface configured to engage with the primary angled surface of the wedge.

Abstract: A firing head assembly is described. The firing head assembly includes a tubular housing, upper piston and lower pistons, and a compressible member arranged within a lumen of the tubular housing and positioned between the upper and lower pistons. According to an aspect, the assembly includes a safety assembly that includes a sleeve having a zigzag shaped slot therein. The safety assembly may include a key that radially extends from a surface of one of the pistons, through the zigzag shaped slot. The distance between the upper and lower pistons may be adjusted by adjusting a pressure inside the tubular housing and a second pressure outside the tubular housing. The upper and lower pistons may function to operatively adjust the arrangement of the key within the zigzag shaped slot to activate the firing head assembly to either trigger an explosive reaction or to not trigger the explosive reaction.

Abstract: Methods include positioning a downhole completion assembly in a tubular conduit of a downhole tubular of a hydrocarbon well. The downhole completion assembly includes a downhole sub-assembly and an uphole sub-assembly. The methods also include forming a fluid seal within the tubular conduit with the downhole sub-assembly, decoupling the uphole sub-assembly from the downhole sub-assembly, translating the uphole sub-assembly in an uphole direction, perforating the downhole tubular with the uphole sub-assembly, translating the uphole sub-assembly in a downhole direction, coupling the uphole sub-assembly to the downhole sub-assembly, ceasing the fluid seal, and translating the downhole completion assembly in the uphole direction.

Abstract: A method of setting a tandem releasable bridge plug system in a casing includes assembling a tandem bridge plug string including a lower bridge plug on a lower, disconnectable connector, an upper bridge plug on an upper, disconnectable connector which both are initially disabled by a lock and unlockable from topsides, and running in the tandem plug string on a drill pipe string until the lower plug is at its setting target depth; setting and shutting the lower plug; disconnecting the upper plug from the lower plug; pulling up the upper plug to its upper setting target depth; enabling the upper plug by releasing the lock; setting and shutting the upper plug; disconnecting the drill pipe string from the upper plug.

Abstract: A valve collar for a downhole packer includes a flow path. The flow path includes an opening valve and closing valve. The valve collar further includes a lockout valve piston. The lockout valve piston is positioned such that in an unset position, the flow path is open and in a set position, the flow path is blocked by the lockout valve piston. The lockout valve piston may be adapted to be shifted from the unset position to the set position by a pressure spike inside the valve collar. The lockout valve piston may be held in the unset position by a temporary restraint.

Abstract: The invention relates to a probe for sampling a drilling fluid comprising a handle extending along an axis, and a sampling head located at a first end of the handle, the head defining an inner space opening outward through an opening. The head comprises a filtration device comprising a filtering wall disposed through the opening; and an extraction duct extending into the handle and opening into the inner space of the head. The filtration device comprises a cleaning blade designed to sweep an outer face of the filtering wall, the blade being mounted to move in translation in a direction parallel to the axis.

Abstract: A slip insert is provided. The slip insert may include a concave surface formed therein. An edge can be formed between a first two-dimensional planer surface and the concave surface. The slip insert may include an edge formed between an intersection of a first two-dimensional planer surface and a second two-dimensional planer surface extending form the concave surface.

Abstract: A circulation test tool and method of performing a circulation test in a wellbore during single-trip casing cutting and removal. An anchor mechanism (20), a mechanical-set retrievable packer (22) and a cutting mechanism (18) allow gripping and cutting of casing (14) with the mechanical set-retrievable packer (22) being set after the cut to carry out the circulation test. The well is kept under control during the cut by application of tension on the drill string to set the packer (22) at any time. The arrangement provides full annulus flow pass at the packer during cutting. Embodiments describe additional features of a drill to dress a cement plug or a settable bridge plug.

Abstract: A single-set anti-extrusion ring has a plurality of ring segments with a mating face on each end. Each mating face has a 3-dimensionally curved topology and the first mating face is a mirror image of the second mating face so the ring segments fit together to form and anti-extrusion ring without gaps in an unexpanded condition, and no straight path through the anti-extrusion ring in an expanded condition.

Abstract: A toe sleeve that is configured to disconnect from casing. More specifically, a toe sleeve that is configured to shear from casing creating a dynamic opening that does not get plugged.

Abstract: Disclosed herein are embodiments of a packer assembly and a well system. In one embodiment, a packer assembly includes an inner mandrel; a packing element at least partially surrounding the inner mandrel; a packing element activation sleeve coupled to the packing element; a hydrostatic setting assembly engageable with the packing element activation sleeve; and a hydraulic setting assembly positioned between the packing element and the hydrostatic setting assembly. The hydrostatic setting assembly includes a hydrostatic piston; a hydrostatic prop piston engageable to push the hydrostatic piston to engage the packing element activation sleeve; and a hydrostatic locking mechanism to maintain the hydrostatic piston in a locked position.

Abstract: A well bore integrity test tool (10) and method of pressure integrity testing a well bore by performing positive and negative pressure tests in a well bore in multiple locations in the well and on the same trip as other operations in the well bore. The tool includes a resettable anchor mechanism (20) and a tension set packer assembly (22). An embodiment of performing a dress-off, integrity testing, casing cutting and pulling in a single trip for well abandonment is described.

Abstract: Disclosed is an assembly for disconnecting portions of a downhole tubular string, such as a drill stem or drill string, and removing an upper portion of the tubular string from the lower stuck portion in a well. The disconnect assembly includes a connection between joints of two portions of the tubular string. The assembly includes two tubular members and an inner sleeve having two splines each with different angular pitches or teeth counts. The assembly may include a rotary shouldered threaded connection, wherein the two tubular portions are disconnectable at the rotary shouldered threaded connection in the assembly. The assembly may include a sleeve lock, a selective no-go for landing in a profile, and a selectively deployable unlocking and unblocking tool for activating the assembly. The assembly may include connectable cylindrical members other than downhole tubulars.

Abstract: Methods of plugging a hydrocarbon well by using degradable plugs plus a degradable tape to ensure pressure testing to 10,000 psi. When the plug is no longer needed, a degradation fluid or fluids are pumped downhole and that fluid or fluids degrade the degradable plugs and degradable tape, thus avoiding the production of any solids large enough to clog or block equipment.

Abstract: An anchor module has an inner mandrel having a through bore, a slips device, upper and lower slips supports, and a spring device radially outside of the inner mandrel. The slips device is biased to a run state. A fluid actuation system counteracts the biasing force and includes a lower piston axially displaceable within a lower fluid chamber, an upper piston axially displaceable within an upper fluid chamber, and a fluid restriction provided in the bore. A lower fluid line is provided between the bore and the lower fluid chamber. The upper and lower pistons are connected to the lower slips device. An upper fluid line is between the bore and the upper fluid chamber. A cross sectional area of the fluid bore at the entrance of the upper fluid line smaller than the cross sectional area of the fluid bore at the entrance of the lower fluid line.

Abstract: The disclosed embodiments include a coupler assembly and method for conveying a single piece liner hanger body. In one embodiment, the coupler assembly includes a nut, a load transfer sleeve, a locking dog retainer, a garter spring, a locking dog, a collet, an outer collet mandrel, and a collet prop mandrel. As described herein, components of the coupler assembly are assembled and installed within the inner diameter of the single piece liner hanger body for engaging with a liner hanger sub-assembly attached to a miming tool.

Abstract: A modular pressure cylinder for a downhole tool has an active mandrel tube that supports a modular pressure cylinder. Pistons of the modular pressure cylinder are respectively interconnected and cylinder walls of modular pressure cylinder are respectively interconnected. When fluid is pumped through a tubing string into the downhole tool, the pistons are urged in one direction while the cylinder walls are urged in an opposite direction along an axis of the active mandrel tube.

Abstract: A BHA features an MWD tool connected to a running tool supporting a whipstock that is connected to an open hole anchor. The anchor is flow set and after the anchor is set the running tool collets release from the whipstock to allow cement to be pumped through the anchor to hold the set position. The collets are released from the whipstock also with flow and after the anchor has been set. One way is to use nozzles in series. Another is to run in with a ball on the anchor seat, set the anchor and blow out the ball seat so flow can again be used to release the running tool collets. Another is suspending a ball above the anchor seat, releasing the ball with pressure cycle, open another flow passage to allow collet release of the whipstock. Finally, pressure can be used to release the running tool collets.

Abstract: Downhole setting systems and methods for setting downhole tools in subterranean formations. An example downhole setting system comprises a downhole setting assembly and a downhole tool configured to be set by the downhole setting assembly. The downhole setting assembly comprises a setting piston, and a mating element that physically constrains the setting piston from translating; the mating element configured to release and permit the setting piston to translate.

Abstract: A wellbore isolation is introduced into a wellbore and includes an elongate body defining an interior and comprising an upper sub, a lower sub, and a mandrel extending therebetween. A sealing element is disposed about the mandrel and upper and lower slip assemblies are positioned on opposing axial ends of the sealing element. A setting piston is positioned within a piston chamber defined by the lower sub and the mandrel, and a mandrel plugging device is positioned within the mandrel. The mandrel plugging device plugs the interior and transitions between occluding setting ports defined in the mandrel and exposed the setting ports to facilitate fluid communication between the interior and the piston chamber. The interior is pressurized to actuate the setting piston and set the lower slip assembly, and further pressurized to move the mandrel and set the upper slip assembly.

Abstract: Hydraulic setting tools, packer setting systems, and methods thereof are provided. The hydraulic setting tool includes a mandrel containing a main flow path, a piston housing surrounding at least a portion of the mandrel, and a piston disposed between the piston housing and the mandrel. A cavity is defined at least partially between the piston, the piston housing, and the mandrel. The tool also includes a port passing through the mandrel and configured to provide fluid communication between the main flow path and of the cavity, and an isolation sleeve located within the mandrel and movable along the main flow path between a closed position and an opened position to control the fluid communication between the main flow path and the cavity via the port. A remotely activated valve is located downstream from the isolation sleeve along the main flow path and controls the fluid passing therethrough.

Abstract: A hydraulic anchoring assembly (10, 10a), and method of its use, for anchoring and sealing an insertable progressing cavity pump on rods in a well. The assembly (10, 10a) has one or more cup seals (42, 42a), upstream of one or more inflatable packers (14, 14a) upstream of one or more hydraulic slips (16). The cup seals (42, 42a) provide a pressure differential for inflation of the upstream most inflatable packer (14), which in turn provides a pressure differential for the downstream inflatable packer(s) (14a) to inflate to produce a fluid tight seal between the insertable progressing cavity pump and the well. In highly deviated wells the up seals (42, 42a) can be used to pump the hydraulic anchoring assembly (10, 10a) down the well in situations where the rods would otherwise buckle.

Abstract: A straddle packer has a multicomponent mandrel with an active mandrel component. A modular pressure cylinder reciprocates within a limited range over the active mandrel component. Pistons the modular pressure cylinder are respectively interconnected and cylinder walls of modular pressure cylinder are respectively interconnected. When fluid is pumped through a tubing string into the straddle packer, the pistons are urged in one direction along an axis of the active mandrel component while the cylinder walls are urged in an opposite direction along the axis to simultaneously compress spaced-apart packers of the straddle packer to a packer set condition.

Abstract: A method of setting a tandem releasable bridge plug system in a casing includes assembling a tandem bridge plug string including a lower bridge plug and an upper bridge plug. Both the upper bridge plug and the upper connector are initially disabled by a lock and unlockable from topsides; running in the tandem plug string on a drill pipe string until the lower plug is at its setting target depth in the casing; setting and shutting the lower plug; disconnecting the upper plug from the lower plug; pulling up the upper plug to its upper setting target depth in the casing, enabling the upper plug by releasing the lock; venting annulus gas to a central bore of the upper plug through a radial aperture below a packer of the upper plug and below a ball valve; shutting said ball valve in said central bore the upper plug; and disconnecting the drill pipe string from the upper plug.

Abstract: A technique facilitates temporary locking of a mechanical packer to prevent inadvertent actuation of the mechanical packer. The mechanical packer may be set via manipulation of a setting mandrel which works in cooperation with a releasable locking mechanism. The releasable locking mechanism may be initially locked against the setting mandrel and held in place via a piston, e.g. an annular piston, received in a piston chamber, e.g. an annular chamber surrounding the setting mandrel. The piston may be selectively shifted via pressure applied in the piston chamber so as to release the releasable locking mechanism, thus enabling actuation of the mechanical packer.

Abstract: A retrievable packer device for use in a wellbore includes first and second end rings configured to be mounted on a base member and a deformable sleeve extending from the first end ring to the second end ring and configured to extend around the base member. A swellable sleeve is mounted on the deformable sleeve.

Abstract: A dual-action hydraulically operable anchor includes a hydraulic anchor body for positioning a whipstock in a wellbore. A split clamp retains an upper sub and the hydraulic anchor body. A lower cap guides the hydraulic anchor within the wellbore. The floating mandrel transmits a hydraulic fluid into the fixed housing, transmitting compressive force from the upper hydraulic piston or from mechanical force applied to the whipstock above and adjoining the hydraulic anchor. The lower hydraulic piston operates along the floating mandrel using transmitted hydraulic fluid. A T-slot adapter and a slip move from a flush position along the fixed housing to an extended position along the fixed housing such that the slip firmly engages the wellbore to hold the hydraulic anchor and the whipstock in a fixed position for providing a path for lateral drilling outside the wellbore.

Abstract: Wellbore isolation devices may be produced with wear bands and slips having modified surfaces to change the frictional properties between these components and the surrounding wellbore surface. A wellbore isolation device may include: a mandrel; slips disposed circumferentially about the mandrel and in a first position along the mandrel. The slips comprise particles coupled thereto forming a modified surface. The particles comprise at least some sharp protrusions. At least one packer element is disposed along the mandrel and in a second position along the mandrel.

Abstract: A downhole wellbore isolation tool includes an elastomeric sealing element for engaging a casing member or another tubular member in a wellbore. The isolation tool includes one or more expandable slips for gripping the tubular member and holding the isolation tool in place. The sealing element has an axial end in direct contact with an abutment surface of the expandable slip such that the slip limits, if not eliminates, unwanted extrusion of the sealing element, e.g., upon setting of the isolation tool. The expandable slips may be constructed of a plurality of slip elements, and the elastomeric sealing element may flow into gaps defined between the slip elements when the isolation tool is set. The slip segments and other components of the isolation tool may be constructed of a dissolvable material to facilitate removal of the isolation tool from the wellbore.

Abstract: A technique facilitates hanging of a liner in a borehole. According to the technique, a liner hanger and a liner may be deployed downhole into a borehole. A wellbore anchoring device of the liner hanger is initially actuated to engage a surrounding surface and to resist downward movement of the liner. Additionally, a hold down anchor is subsequently actuated to resist upward movement of the liner. The hold down anchor may be released via mechanical manipulation of the liner hanger.

Abstract: A packer for sealing in a tubular includes a mandrel on which a packing element is disposed between booster pistons. Each piston defines a sealed chamber with housed areas of the mandrel. A setting force compresses packing element between the booster piston, which shear free. Ratchet mechanisms including ratchet sleeves and body lock rings disposed between the pistons and the housed areas initially allow the pistons to move in a direction away from the packing element, which expands the respective sealed chamber. Thereafter, in response to a pressure differential across the respective sealed chamber, the ratchet mechanisms each permit urging of the respective piston toward the packing element while preventing retraction of respective piston in the opposite direction.

Abstract: A packer comprising a mandrel having a radially directed port disposed therein and a passageway axially disposed therein and a packer element disposed around a portion of the mandrel. The packer further includes a housing disposed around a portion of the mandrel creating an annulus area between the mandrel and the housing, the housing is disposed adjacent to the packer element to squeeze the packer element and axially expand the annulus area when fluid flows through the radially directed port and into the annulus area above a fluid pressure threshold. The packer can be included in a downhole assembly having an upper packer and a lower packer. A method of using the packer includes placing the packer into a wellbore to seal one zone from another and pumping fluid into the packer to set the packer element against a casing in the wellbore. A method of using the assembly that incorporates the upper packer and the lower packer is also described.

Abstract: A setting tool for use in setting plugs downhole using opposing pistons to axially compress a plug, thereby causing it to radially expand.

Abstract: An annular barrier has a tubular part, and a downhole expandable tubular to be expanded in an annulus downhole from a first outer diameter to a second outer diameter to abut against an inner face of a casing or borehole. The downhole expandable tubular has a first end section, a second end section and an intermediate section between the first end section and the second end section, the downhole expandable tubular surrounding the tubular part. Each end section of the downhole expandable tubular is connected with the tubular part and extends along a longitudinal axis, and defines an annular barrier space between the tubular part and the downhole expandable tubular. The tubular is made from one metal tubular blank of one metal material, the metal material of the end sections having a higher yield strength than the metal material of the intermediate section.

Abstract: A method of fracturing a formation penetrated by a wellbore, the method includes fracturing the formation by increasing an annulus pressure in the wellbore above a fracture initiation pressure. The method also includes decreasing the annulus pressure below a fracture closure pressure, and re-fracturing the formation by increasing the annulus pressure in the wellbore above the fracture initiation pressure.

Abstract: A setting mechanism for a liner hanger to be secured within the casing of an oil/gas well includes an expandable hydraulic chamber a portion of which is connected to a setting collar positioned around the liner hanger. Expansion of the chamber will cause the setting collar to radially move one or more slips having a gripping surface into contact with an inner surface of the casing.

Abstract: A system includes a hanger running tool and a pressure port. The hanger running tool includes an upper body, a lower body disposed about the upper body, a first lock ring disposed between the upper body and the lower body, the first lock ring comprising a tapered top surface, a first push ring disposed between the upper body and the lower body, the first push ring comprising a tapered bottom surface that interfaces with the tapered top surface of the first lock ring, an upper piston disposed about the upper body, and a lower piston disposed about the first lock ring, the first push ring, and the lower body, extending axially downward. The pressure port is in fluid communication with a volume between the upper piston and the lower piston.

Abstract: The present invention relates to a packer device (1) for sealing against an inner surface of a surrounding pipe or casing string (4), preferably for isolating zones or sections in an oil well, comprising a tubing body (3) and at least one sealing element (7a, b), where a cylinder/piston arrangement (2) comprises a cylinder (5) having a closed volume containing a fluid, such as a gas or liquid, arranged to expand when exposed to heat thereby exerting a mechanically pressure on movable elements (12), initially locked in a fixed position by means of at least one fixing element, such as a shear member (6), and where the movable elements (12) are adapted to be released into an operative state at a predetermined axial force, exerted by the closed volume in the cylinder (5), resulting in that the at least one sealing element (7a, b) is pressed radially outwardly in such a way that it seals the packer device (1) against the surrounding pipe-/casing string (4).

Abstract: A new cement valve is disclosed for use in the production of an oil or gas well where hydraulic fracturing has been employed. In particular, the embodiments include a cement valve having a reclosable valve. When properly located, a first piston sleeve is hydraulically actuated to open the cement ports on the tool. After the cement has been pumped through the tool and the cement ports to a wellbore annulus, a blocking ball is dropped to stop flow through the tool. The tool is internally pressurized. The pressure overcomes shear pins to force downward movement of a ball housing inside the cement valve. This movement translates a travelling pin along a guide path, which rotates a ball valve inside the ball housing, releasing the blocking ball to open up the internal flow path through the cement valve at the same time the cement ports are closed.