Abstract: An example downhole tool may include a first component and a second component. A first seal may be positioned between the first component and the second component, and a first energizer may be positioned between the first seal and the first component. The first seal may comprise a polyaryletherketone (PAEK) material. The first energizer may be a compressible material. The PAEK material may be at least one of polyetherketone (PEK), polyether ether ketone (PEEK), polyetherketoneketone (PEKK), polyehtheretherketoneketone (PEEKK), and polyetherketoneether-ketoneketone (PEKEKK).

Abstract: A system and method for adapting a wireline tool to operate in environments for which it was not designed is disclosed. The system includes a pressure housing within which a wireline tool may be secured between a first connector subassembly mated to one end of the pressure housing and a second connector subassembly mated to the other end of the pressure housing. The first connector subassembly includes an electrical connector subassembly by which the wireline tool may be electrically connected to the wireline. The method includes disposing a wireline tool within a pressure housing between a first connector subassembly mated to one end of the pressure housing and a second connector subassembly mated to the other end of the pressure housing and electrically connecting the wireline tool to an electrical connector subassembly in the first connector subassembly, by which the wireline tool may be electrically connected to the wireline.

Abstract: An example wellbore system includes a wellbore at least partially lined with casing and having an upper control line extending on an exterior of the casing and conveying one or more first communication media, a casing nipple provided on the casing and defining a nipple profile, an upper control line connector coupled to the casing nipple and communicably coupled to the upper control line, a connector assembly arranged on a wellbore tubing extendable within the wellbore and defining an anchor profile engageble with the nipple profile, and a lower control line connector coupled to the connector assembly and communicably coupled to a lower control line extending along the wellbore tubing and conveying one or more second communication media, wherein the one or more first and second communication media are communicably coupled by radially expanding and rotating the lower control line connector with respect to the upper control line connector and thereby mating the upper and lower control line connectors.

Abstract: Methods of coupling a control line including axially aligning a first connector with a second connector, the first connector having a first housing and a pin connector, and the second connector having a second housing and a box connector. And angularly rotating one or both of the first and second connectors with respect to each other and thereby angularly aligning a pin mating face provided on the pin connector with a box mating face provided on the box connector, mating the pin connector to the box connector by further angularly rotating one or both of the first and second connectors. And communicably coupling one or more first communication media in the pin connector with one or more second communication media in the box connector.

Abstract: A method and apparatus for electronically coupling electronics in downhole tools without a harness is described. The apparatus includes one or more electronics boards, which may be disposed around a tool insert and electronically coupled using a backplane. The backplane may comprise one or more backplane segments, and each of the segments may comprise two printed circuit boards communicatively coupled to each other. The two printed circuit boards may be on opposite sides of a base metal ring and may be coupled to each other via connectors in a cavity of the base metal ring. Dampers may be placed between the base metal ring and each of the printed circuit boards. The printed circuit boards my optionally include an identification chip for storing information concerning the electronics boards coupled to the backplane. Additionally or alternatively, the printed circuit boards may optionally include active device chips that dynamically route signals based on which electronics boards are coupled to the backplane.

Abstract: A drillstring comprising a length of drillpipes and a bottomhole assembly disposed at a downhole end of the length of drillpipes. The bottomhole assembly comprises a transition section proximal to the end of the length of drillpipes to reduce vibration of the bottomhole assembly during drilling. The transition section varies gradually in acoustic impedance between the acoustic impedance of the drillstring above the transition section and the acoustic impedance of the bottomhole assembly below the transition section. The transition section forms at least thirty percent (30%) of the total length of the bottomhole assembly.

Abstract: A shock sleeve is positioned above a UBHO sleeve, and both are received inside a substantially tubular sub collar. The shock sleeve is free to reciprocate with respect to the UBHO sleeve and sub collar. A mud pulse transmitter valve is received into the shock sleeve. The shock sleeve is interposed between upper and lower shock springs, which provide compensating compression spring bias to dampen the transmitter valve (as received in the shock sleeve) from vibration or shock forces experienced by the sub collar. At least one shock absorbing compression ring interposed between mating portions of the shock sleeve and transmitter valve also dampens the transmitter valve against vibration or shock. An optional mud filter received over the shock sleeve removes particulate matter from drilling fluid before it encounters the shock sleeve.

Abstract: A stabilizer, drill bit, or other component of a bottom hole assembly for use in drilling a borehole includes an elongate and generally cylindrical body, a flow bore in the body, a plurality of outwardly-extending blades, with a valley disposed between adjacent blades. A ring segment that is spaced from the body and extends across at least one valley to define a flow passage through which cuttings-laden drilling mud is conveyed with an upwardly-direct trajectory. The body includes a hole or passageway for conveying drilling mud from the flow bore to between the blades. The passageway terminates in an exit directed toward the flow passage so as to provide fresh drilling mud with a trajectory such that the fluid passes through the flow passage.

Abstract: A centralizer includes one or more centralizer fins radially extending from a body of the centralizer. The centralizer fins may include one or more chambers extending through the outer surfaces of the centralizer fins. The one or more chambers may change shape in response to a compression force being applied to the centralizer fins to cause the centralizer fins to deform. The centralizer fins may be deformed for installation of the centralizer in a drill collar. The centralizer may also include a split-ring clamp for coupling the centralizer to a drilling tool positioned in a through-bore of the centralizer body. The split-ring clamp may apply a load on the drilling tool in response to an end cap being torqued to an end portion of the centralizer body.

Abstract: In accordance with some embodiments of the present disclosure, a downhole drilling tool comprises a bit body, a blade on an exterior portion of the bit body, and a gage pad on the blade. The gage pad includes a ball retainer and a ball located in the ball retainer such that an exposed portion of the ball is positioned to contact a wellbore and rotate in response to frictional engagement with the wellbore.

Abstract: A method of installing a flexible line between an offshore platform and a subsea structure includes at least partially deploying the line in the water using an installation vessel located outside of an exclusion zone in the vicinity of the platform, including lowering a topside end of the line either to the seabed or to an intermediate location between the seabed and the platform. The method further includes pulling the topside end to a position within the exclusion zone and winching the topside end up to the platform, and coupling the topside end to the platform.

Abstract: An integral self-contained drillstring compensator includes at least one high pressure air cylinder, an accumulator, and a compensating cylinder, which are fluidly coupled to one another. The high pressure air cylinders include a compressible gas that is communicable to the accumulator, which has fluid included therein. The compressible gas provides a pressure on the fluid, thereby allowing the fluid to communicable between the accumulator and the compensating cylinder. The fluid causes a cylinder rod within the compensating cylinder to extend and retract from the compensating cylinder, thereby providing compensation during heaves. The drillstring compensator optionally includes a low pressure air cylinder to store a low pressure compressible fluid that communicates with the compensating cylinder.

Abstract: A device for holding a bush member with a drill column of a machine is disclosed. The device includes a first member adapted to engage with the bush member. The device also includes a second member spaced apart from the first member. The second member is coupled to the first member by a connecting member. The second member includes an opening to receive the drill column. The device includes a flange member removably coupled to the second member. The flange member includes a first engagement portion adapted to contact with an outer surface of the drill column having a first perimeter. The first engagement portion is supported on a step portion defined in the drill column.

Abstract: A slips assembly for a drilling rig and methods. The slips assembly includes a body, a plurality of slips disposed within the body and configured to extend radially inward to engage a tubular, and to retract radially outward to form a gap between the tubular and the plurality of slips, and sensors configured to detect a force on the plurality of slips generated by the plurality of slips engaging the tubular.

Abstract: A portable lifting device is provided for adjusting pump spacing of a production well. The lifting device rests directly on a well head flange and provides an expansive force between the flange and a temporary polish rod clamp or collet device is attached to a polished rod extending into the well head. The device includes first and second hydraulic cylinders for simultaneously lifting the polished rod to provide a gap between a carrier bar and a polished rod clamp.

Abstract: Methods for making a threaded connection between an upper tubular and a lower tubular using an oilfield tubular spinner and a torque wrench, including holding the lower tubular with the torque wrench, frictionally engaging the upper tubular with the tubular spinner, operating a motor of the tubular spinner to spin-in and shoulder-up a tubular connection between the upper tubular and the lower tubular, establishing a threshold hydraulic system pressure that indicates a shouldered-up condition, monitoring, with a detection system, a hydraulic system pressure of the motor during spin-in and shoulder-up, and maintaining the threshold hydraulic system pressure to operate the motor for a selected period of time after the threshold hydraulic system pressure is reached. An oilfield tubular spinner for an oilfield tubular wrench is also provided.

Abstract: Techniques and systems to reduce contact of a cable with a top drive. A cable guide may be mounted to one or more bails supporting the top drive and may operate to extend a distance between a cable passing along a length of the top drive. The cable guide may include both an upper guide assembly and a lower guide assembly. Each of the upper guide assembly and the lower guide assembly may both be coupled to one or more bails supporting the top drive in a serial manner.

Abstract: A method for operating an electrical submersible pump, ESP, lifted well, the method comprising: measuring a characteristic of the well or a characteristic of a device associated with the well; generating a first control signal for instructing a change in the operation of the ESP; generating a second control signal for instructing a change in the operation of a further device associated with the well; wherein a degree of change in each of the first and second control signals is dependent on the outcome of the measuring and on a known effect caused by sending at least one of said first control signal to the ESP or said second control signal to the further device associated with the well; and sending the first control signal to the ESP and the second control signal to the further device associated with the well.

Abstract: A system (10) for drilling a borehole (14) in a subterranean formation (16) containing a fluid (18), comprising: an outer tube (24) defining an outer tube distal end (26) configured for attaching a drill bit (12) thereto and a flow controller receiving section (27) spaced apart therefrom; a flow controller (28) including a flow controller body (30) defining body proximal and distal ends (32 and 34) and securable to the outer tube (24) in the flow controller receiving section (27); and a drilling accessory (36) insertable in the outer tube (24) and through the flow controller (28). The flow controller (28) is movable between open and closed configurations. In the open configuration, the flow controller (28) allows passage of the drilling accessory (36) therethrough. In the closed configuration, the flow controller (28) hinders flow of the fluid therethrough towards the borehole proximal end (20) when the flow controller (28) is located closer to the borehole proximal end (20) than the fluid (18).

Abstract: A deflector assembly includes an upper deflector arranged within a main bore of a wellbore, the upper deflector having first and second plates spaced apart by a distance. At least one of the first and second plates includes a ramped surface. A lower deflector is arranged within the main bore, the lower deflector defining a first conduit and a second conduit. One of the first and second conduits is in communication with a lower portion of the main bore and another of the first and second conduits is in communication with a lateral bore. The upper and lower deflectors are configured to direct a bullnose assembly into either the lateral bore or the lower portion of the main bore based on a size of a bullnose tip of the bullnose assembly.

Abstract: A first lobe is fixedly coupled to a wall of a housing. A fixed pivot is fixedly coupled to the first lobe and to the wall of the housing. A chamber pivot is rotatably coupled to the first lobe. A floating pivot is rotatably coupled to the chamber pivot. A first link is rotatably coupled to the floating pivot. A slip pivot is rotatably coupled to the first link. A second link is rotatably coupled to the slip pivot and to the fixed pivot. A pad is coupled to the slip pivot. An actuator is coupled to the first lobe and to the second lobe.

Abstract: An anchoring tool is presented having radially pivoting arms which are moved from a run-in position to a set position. In the run-in position the un-articulated arms are positioned radially inward to provide a small tool outer diameter. Upon setting, the arms are pivoted radially outward into gripping engagement with a downhole tubular, such as a liner or casing. The pivot arms define a cam surface for interaction with corresponding wedges, where the cam surface allows for greater radial expansion of the arms.

Abstract: A severance tool for severing a target is described. The severance tool comprises a housing, a plurality of focused energetics, each focused energetic adapted to release energy in a preferred direction and a trigger mechanism adapted to detonate the focused energetics. The focused energetics are aligned such that, on impact with a target comprising a material, the energy released by one of said focused energetics cooperates with the energy released by another of said focused energetics to establish a separating force within the target material.

Abstract: A downhole tool or a member thereof, preferably a ball sealer, a ball seat, a frac plug or a bridge plug, comprising a degradable resin composition containing a degradable resin and a toughness enhancing agent, in which the degradable resin composition has an izod impact strength (unnotched) of 1,000 J/m or more, a tensile elongation of 3% or more, and a tensile strength of 30 MPa or more; a degradable resin composition for a downhole tool (member) containing 60 to 99.9 mass % of the degradable resin and 0.1 to 40 mass % of the toughness enhancing agent; and a method for recovering a hydrocarbon resource using the downhole tool (member).

Abstract: In aspects, the present disclosure provides a perforating gun that includes a carrier tube, and a charge tube assembly. The carrier tube includes a bore and a groove formed along an inner surface. The charge tube assembly is disposed in the bore of the carrier tube and includes a charge tube, an alignment end plate, an insertion end plate, a retention member, shaped charges, and a detonating cord. The charge tube has a plurality of shaped charge openings, a plurality of post openings, a first end, and a second end. The alignment end plate is connected to the first end of the charge tube. The insertion end plate is connected to the second end of the charge tube. The shaped charges are disposed in each of the shaped charge openings. Each shaped charge has a post projecting out of one post opening. The detonating cord is connected to each of the projecting posts.

Abstract: A flow restriction device for restricting flow through a conduit.

Abstract: An impact apparatus conveyable in a tool string within a wellbore comprises a mandrel, a first impact feature, and a latch pin retainer encircling an end of the mandrel. A release sleeve encircles a portion of the latch pin retainer and includes a radial recess. Latch pins retained by the latch pin retainer are slidable into and out of the radial recess, and prevent disengagement of the mandrel end from the latch pin retainer when not extending into the radial recess. A release member electromagnetically causes relative translation of the latch pin retainer and the release sleeve, including aligning the latch pins with the radial recess and thereby permitting the disengagement. A second impact feature is positioned to impact the first impact feature in response to the disengagement when the impact apparatus is under tension.

Abstract: Method, apparatus and a system is provided for dry launching balls. One releases a ball from the stored balls, stages the ball in a staging or launching block for exposure to fluids and then injects the dropped ball into the wellbore. Fluid in the isolated staging block is removed by pump or by drainage, minimizing risk of fluid reaching stored dry balls thereabove. This method can then be repeated for subsequent balls to be dropped into the wellbore. Further, a system for reducing the fall energy of a dropped ball comprises providing one or more impact energy dampeners along a ball drop path including providing an angled sidewall of the path bore, one more elements to periodically engage a dropped ball, or to provide a liquid sump to receive a dropped ball.

Abstract: A system comprises an outer housing, an inner housing, a first seal and a second seal. The outer housing comprises an inlet and an outlet. The inner housing is mounted inside the outer housing. The inner housing is dimensioned relative to the outer housing to allow for an annular space between the outer housing and the inner housing. The first seal and the second seal are mounted in the annular space so as to define a fluid chamber enclosed by the outer housing, the inner housing, the first seal and the second seal. The inlet and the outlet are in communication with the fluid chamber.

Abstract: Systems and related methods are disclosed for applying electrorheological fluids in hydro-carbon-producing environments. The systems include a fluid-retaining member having a conductive inner surface and a conductive outer surface. The fluid-retaining member retains a smart fluid. The systems also include a controller that is electrically coupled to a power source and at least one of the conductive inner surface and conductive outer surface of the fluid-retaining member to actuate an electric field or magnetic field across fluid-retaining member. Actuation of the electric field or magnetic field results in a near instantaneous increase in the viscosity of the fluid, causing the fluid to solidify, nearly solidify, gel or otherwise increase in viscosity. The actuated fluid retaining member may be used as a well casing, an isolator, a blowout inhibitor, or in a well insulation system to absorb energy in the event of an explosion.

Abstract: The present disclosure generally relates to downhole tools comprising aqueous-degradable sealing elements and, more specifically, to downhole tools comprising a body and an aqueous-degradable sealing element, wherein at least a portion of the body is also degradable upon exposure to a wellbore environment. A downhole tool that includes a body, wherein at least a portion of the body is degradable when exposed to a wellbore environment; and at least one aqueous-degradable sealing element composed of an aqueous-degradable elastomer, wherein the aqueous-degradable sealing element degrades when exposed to an aqueous fluid in the wellbore environment.

Abstract: Provided is a degradable seal member for downhole tools, the member being formed from a degradable polymer material that is preferred to be a thermoplastic polymer material or a polymer material including an ester bond, an amide bond, or a urethane bond, and that is further preferred to be a polymer material that contains an aliphatic polyester. It is preferred that the degradable seal member exhibits a bending elastic modulus of 0.01 to 8 GPa at 23° C., further preferred that a stable state is maintained in a dry environment and that degradation in a fluid of a temperature not less than 66° C. is possible, and also preferred that a molded article has an annular shape. Also provided are a downhole tool such as a plug for well drilling and completion, and a method of well drilling and completion.

Abstract: A compression set sealing element preferably 85A-95A TDI-Ester Polyurethane is compressed axially and retained against extrusion by CEM anti-extrusion rings. The compressed state of the sealing element is locked in by a degradable lock ring assembly. The mandrel is secured to an upper end of a slip cone and a breakable slip ring is secured by a wireline setting tool until the set position is reached. The slip ring breaks into segments that are pulled up the slip cone as the setting tool pushes on a sleeve to axially compress the sealing element and lock in the set. The sealing element is retained against extrusion by CEM anti-extrusion rings. When the setting tool is removed a ball seat is exposed for delivery of a ball to build pressure into the formation for fracturing. The entirety of the plug then disintegrates from well fluid exposure.

Abstract: A compression set sealing element preferably 85A-95A TDI-Ester Polyurethane is compressed axially and retained against extrusion by CEM anti-extrusion rings. The compressed state of the sealing element is locked in by a degradable lock ring assembly. The mandrel is secured to an upper end of a slip cone and a breakable slip ring is secured by a wireline setting tool until the set position is reached. The slip ring breaks into segments that are pulled up the slip cone as the setting tool pushes on a sleeve to axially compress the sealing element and lock in the set. The sealing element is retained against extrusion by CEM anti-extrusion rings. When the setting tool is removed a ball seat is exposed for delivery of a ball to build pressure into the formation for fracturing. The entirety of the plug then disintegrates from well fluid exposure.

Abstract: A system including a hydraulic tool configured to energize a lock ring system and a seal assembly with a hydraulic fluid, wherein the hydraulic tool including a hydraulic body configured to couple to a hydraulic fluid source, a first piston configured to move axially with respect to the hydraulic body to energize the seal assembly, and a second piston configured to move axially with respect to the hydraulic body to energize the lock ring system, wherein the first and second pistons are simultaneously exposed to the hydraulic fluid in an opening in the hydraulic body.

Abstract: A packer with a slip assembly utilizing retainable wing projections. The slip assembly is configured for anchoring the packer in a well upon setting. This setting or deployment of the slip assembly involves shearing of wing projections from the sides of the slips. In this way, the retaining of the wings by counterbore projections of the packer ceases to keep individual slips also retained. That is, the shearing now allows the slips to expand radially into the noted anchoring position. Additionally, utilizing this type of wing shearing for setting allows the wings and indeed, the majority of the slips to be of a composite polymer or other readily millable or otherwise removable material. Thus, following the isolation, a more efficient packer removal may be realized.

Abstract: A technique facilitates deployment and operation of actuatable plugs, e.g. frac plugs or bridge plugs. According to one embodiment, the plug comprises a flexible element slidably mounted on a portion of a cone, e.g. an upper cone. The upper cone comprises a tapered surface which works in cooperation with upper slips movably secured to the upper cone. The bridge plug also comprises a lower cone which comprises a lower tapered surface which works in cooperation with lower slips movably secured to the lower cone. Depending on the application, the plug may be constructed with each of these features combined into an overall assembly or with a portion of these features to facilitate plug operation in a specific environment and operation.

Abstract: A subsea wellbore protection (SWP) system. The SWP system includes a wellbore penetrating a subterranean formation beneath a sea floor and a SWP structure positioned below grade with respect to the sea floor. The SWP structure comprises a caisson that encloses a first wellbore equipment component. The first wellbore equipment component is in fluid communication with the wellbore.

Abstract: A borehole tool can include a frangible degradable alloy that includes an oxidizable base element and at least one alloying element.

Abstract: A method can include altering heat energy of a shape memory material of a shape memory material actuator operatively coupled to a valve mechanism of a gas lift valve; responsive to the altering, adjusting the valve mechanism at least in part via the shape memory material actuator; altering heat energy of the shape memory material; and adjusting the valve mechanism at least in part via the shape memory material actuator.

Abstract: An injection valve assembly for use in a well, where pressurized gas or fluid from uphole in the well displaces a perforated valve head from a valve seat, allows for fluid flow of the pressurized gas or fluid into the valve head and further downhole in the well toward an electric submersible pump. A compression spring is coiled around a valve stem connected to the valve head, pushing the valve stem and valve head in an uphole direction opposite to the force from pressurized gas or fluid. The compression spring is in a chamber filled with hydraulic fluid, where the hydraulic fluid can pass through a dampening system assembly and a flow restrictor assembly, thereby regulating the speed at which the valve stem and valve head can move relative to the valve seat.

Abstract: A method and apparatus for filling an annulus between a wellbore and a casing string with cement are provided. A baffle is arranged between a port on a side of the casing string and an interior volume of the casing string. The baffle includes orifices arranged there around that distribute the flow of cement about the circumference. After the cement has been pumped, a sealing sleeve is moved over the baffle and the port and forms a metal-to-metal seal that isolates the baffle and the port from the interior volume of the casing string.

Abstract: Disclosed herein are methods including applying a photo-activated catalyst to a window, directing an ultraviolet light onto the window, producing a bleach via an oxidation reaction, and breaking down organic compounds located on the window using the bleach. Also disclosed herein are systems including an ultraviolet light source and a window having a photo-activated catalyst layer.

Abstract: Methods of protecting a surface of a metallic body against scale formation in a well or pipeline including the steps of: vapor depositing a source material comprising a metal oxide onto the surface of the metallic body; and positioning the metallic body in a wellbore of a well or to form a portion of a pipeline.

Abstract: A method of removing residual proppant from a bottom of a casing after a fracturing operation comprises: circulating a casing flush fluid comprising a carrier and a superabsorbent polymer in the casing; and transporting the residual proppant from the bottom of the casing to a fracture created by a hydraulic fracturing operation. A method for cleaning a wellbore comprises: introducing a cleanout fluid through a conduit inserted into the wellbore, the cleanout fluid comprising a carrier fluid and a superabsorbent polymer; and receiving a returning fluid comprising debris at the surface of the wellbore from an annular space between the conduit and a wall of the wellbore.

Abstract: Apparatus, method, and a containment system for a mud tank The system includes a pan extending from a base of the mud tank and configured to receive fluids leaked therefrom, a fluid sensor coupled with the pan, and a pump in fluid communication with the pan, wherein the pump is configured to remove fluid from the pan when the fluid sensor reads a predetermined threshold fluid level in the pan.

Abstract: The invention concerns a computer implemented method for underbalanced drilling. In one embodiment, the method includes determining a plurality of gas injection rate versus bottom hole pressure curves for a plurality of liquid injection rates for a specified minimum and maximum gas injection rate and a minimum and maximum liquid injection rate. Next, the method determines a set of four interception curves including a minimum motor equivalent liquid rate interception curve, a minimum vertical liquid velocity intercept curve, a minimum horizontal liquid velocity intercept curve, and a maximum motor equivalent liquid rate intercept curve for a specified minimum and maximum mud motor rate range and a minimum horizontal and vertical annulus velocity.

Abstract: This invention is a method of developing a sedimentary basin containing hydrocarbons, by using basin simulation. Starting with gridded representations representative of a basin for each time step of a simulation, for each time step and in each cell of the gridded representation the following steps are performed. First a determination of at least one amount of biogenic gas produced in the cell for the time step is preformed followed by determining at least one amount of biogenic gas dissolved in water present in the cell at the time step, and determining therefrom an amount of free biogenic gas in the cell at the time step; then, accounting for advective transport of the quantity of biogenic gas dissolved in the water of the cell at the time step. Application: petroleum reservoir exploration and development for example.

Abstract: A male connector (3) to be inserted into a female connector (5). The male connector defines a conduit and comprises a locking means (39) operable to engage the female connector to thereby lock the male connector relative to the female connector. The male connector also comprises a release means (17) for unlocking the male connector to permit the male connector to be separated from the female connector. The release means is accessible from within the conduit. There may be a release tool (50) operable to disengage the male connector from the female connector and retain the male connector after the male connector has been disengaged from the female connector.

Abstract: A gravel pack of screen sections separated by blank pipe is accomplished with sleeves around the blank sections that have a smaller run in dimension to allow the gravel to get past the sleeves during the gravel packing. When the gravel packing is complete the sleeves swell or otherwise enlarge to fill the voids where no or insufficient amount of gravel has been deposited. The presence of the enlarged sleeves prevents settling or shifting of the gravel pack away from the screens because voids that would otherwise have been there are filled with the enlarged sleeves. This is more of an issue in wells that are closer to vertical than horizontal.