Patent Publication Number: US-10781674-B2

Title: Liner conveyed compliant screen system

Description:
BACKGROUND 
     Hydrocarbon producing wells are often completed in unconsolidated producing formations containing fines and sand that can flow with produced hydrocarbons (fluids or gas) from the formations. The solid particulates in the produced fluids flow stream can damage equipment and must be removed from the produced fluids. Following drilling of a wellbore through an unconsolidated formation it is often a requirement that the wellbore be completed with a device that retains the sand particles in the formation, but that allows the flow of fluids to be produced. Filters, such as for example, sand screens or compliant screens, are commonly installed in wellbores and a gravel pack operation or the conformance of the screen against the borehole geometry can be performed to assist with the filtering out the fines and sand in the produced fluids and in the stabilizing of the producing formation. 
     The portion of the well above the productive formation is usually lined with one or more steel casing. The annulus between the casing and the wellbore is typically filled with cement to stabilize the casing and prevent fluid flows within the annulus. The wellbore can then be drilled further to drill through the productive formation. A length of blank pipe may be run to provide a second casing (often referred to as a liner) in the wellbore below the existing casing to a location just above the productive formation. At least a portion of the annulus between the liner and the open hole below the casing is normally filled with cement to hold the liner in place and block annular flow of fluids around the liner. A screen assembly can then be run below the liner into the open hole zone to provide a flow path for produced fluids from the producing formation, through the screen and liner and to the cased portion of the well. A flow conduit for produced fluids within the cased portion of the well to the surface is typically a production tubing string. 
     A well completion in an open hole zone generally requires both a sand control operation and a cementing operation. These operations have typically been performed using separate stages and multiple sets of equipment run into the well at different times. For example, a liner may be placed in the well and a cementing assembly may be run into the well to perform cementing of the liner. Once cementing of the liner is completed the cementing assembly is typically removed from the well and a sand control assembly run into the well. Thus, multiple trips into the well have typically been required to place the liner and the screen within the well and to cement the liner. Each trip into the well to position equipment or perform an operation requires additional time and expense and presents a challenge. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         FIG. 1  is a schematic illustration of an offshore oil and gas platform and the drilling of a wellbore through a subterranean formation. 
         FIG. 2  is an elevation view of a cross-section of an example of a subterranean formation and drilling/completion/workover rig in which a sand control operation may be performed in accordance with certain embodiments of the present disclosure. 
         FIGS. 3 a -3 d    illustrate an elevation sectional view of an assembly according to an embodiment, as positioned in a well in preparation for sand control operation and cementing in accordance with certain embodiments of the present disclosure. 
         FIG. 4  is an elevation sectional view of  FIG. 3 , with an inner assembly in a compliant screen activation and/or well treatment/displacement position in accordance with certain embodiments of the present disclosure. 
         FIG. 5  is an elevation sectional view of  FIG. 3 , with an inner assembly in a reverse circulation position after compliant screen activation and/or well treatment/displacement in accordance with certain embodiments of the present disclosure. 
         FIG. 6  is an elevation sectional view of  FIG. 3 , with the inner assembly in a cementing position in accordance with certain embodiments of the present disclosure. 
         FIG. 7  is an elevation sectional view of  FIG. 3 , with the inner assembly in a circulation position after cementing in accordance with certain embodiments of the present disclosure. 
         FIG. 8  is an elevation sectional view of  FIG. 3 , with the inner assembly removed in accordance with certain embodiments of the present disclosure. 
         FIG. 9  is an elevation sectional view of  FIG. 3 , with the inner assembly removed in accordance with certain embodiments of the present disclosure. 
         FIG. 10  is an elevation sectional view of a setting tool in accordance with certain embodiments of the present disclosure. 
         FIGS. 11 a  through 11 f    illustrate cross-sectional and sectional views of a compliant screen assembly according to an embodiment, at its Run-in state, Activation state, and Productive state in accordance with certain embodiments of the present disclosure. 
         FIGS. 12 a  through 12 d    illustrate cross-sectional views of a compliant screen assembly according to an embodiment. 
         FIGS. 13 a  through 13 b    illustrate cross-sectional views of a downhole shutoff collar assembly according to an embodiment. 
         FIG. 14  illustrates an elevation view of a double sideport float shoe assembly according to an embodiment. 
         FIGS. 15 a  through 15 b    illustrate an elevation view of a dart and a wiper plug assembly attached to a liner hanger setting tool according to an embodiment. 
         FIG. 16  illustrates an elevation view of a landing collar with a double sideport float shoe assembly according to an embodiment. 
         FIG. 17  illustrates an elevation view of an eRED® plug assembly according to an embodiment available from Halliburton of Houston Tex. 
     
    
    
     DETAILED DESCRIPTION 
     The following detailed description illustrates embodiments of the present disclosure. These embodiments are described in sufficient detail to enable a person of ordinary skill in the art to practice these embodiments without undue experimentation. It should be understood, however, that the embodiments and examples described herein are given by way of illustration only, and not by way of limitation. Various substitutions, modifications, additions, and rearrangements may be made that remain potential applications of the disclosed techniques. Therefore, the description that follows is not to be taken as limiting on the scope or applications of the appended claims. In particular, an element associated with a particular embodiment should not be limited to association with that particular embodiment but should be assumed to be capable of association with any embodiment discussed herein. 
     Various elements of the embodiments are described with reference to their normal positions when used in a borehole. For example, a screen may be described as being below or downhole from a crossover. For vertical wells, the screen will actually be located below the crossover. For horizontal wells, the screen will be horizontally displaced from the crossover, but will be farther from the surface location of the well as measured through the well. Downhole or below as used herein refers to a position in a well farther from the surface location in the well. 
     An annulus, as used in the embodiments, is generally a space between two generally cylindrical elements formed when a first generally cylindrical element is positioned inside a second generally cylindrical element. For example, a liner is a cylindrical element which may be positioned in a wellbore, the wall of which is generally cylindrical forming an annulus between the liner and the wellbore. While drawings of such arrangements typically show the inner element centrally positioned in the second, it should be understood that inner element may be offset and may actually contact a surface of the outer element at some radial location, e.g. on the lower side of a horizontal well. The width of an annulus is therefore typically not the same in all radial directions. 
     Cementing operations in a well and equipment used for such operations are generally well known in the well completion field. In general, the equipment provides a flow path through which cement may be flowed from a work string into an annulus between a casing, liner, or other oilfield tubular element and a well. Since the well is normally filled with a fluid, e.g. drilling fluid, completion fluid, etc., the equipment also includes a return flow path for fluid displaced by cement during the cementing operation. 
     Sand Control operations in a well and equipment used for such operations are also generally well known in the well completion field. A complete sand control assembly may be considered to include a screen or other filter element and length of blank pipe extending from the screen, both of which are to be installed in a well, as well as equipment for placing a gravel pack activate compliant screen and/or perform a fluid displacement/treatment around the screen in the well. The equipment typically includes a work string having a packer and cross over assembly and a wash pipe extending below the cross over to the bottom of the screen. When properly positioned for a sand control operation, the packer seals the annulus between the work string and the well above the screen. A fluid, i.e mud cake breaker, acid, brine . . . is then flowed down the work string to the crossover which directs the fluids into the annulus below the packer. The fluid flows through the screen into the wash pipe back up to the crossover which directs the return flow into the annulus above the packer. Alternatively, the fluid can be pumped down the annulus through the return port by-passing the crossover, down the washpipe. It will then flow along the open hole through the crossover and up the workstring. By plugging the bottom of the compliant screen, the screen can be activated by pressurizing in the same flow path than previously described. A packer may be used between the work string and the casing, liner, etc. to prevent cement from entering the annulus between the work string and the casing, liner, etc. 
     A well completion in an open hole zone generally requires the running of a liner, a cementing operation, the running of a screen, and a sand control operation. These completion operations are well known but are typically performed using multiple sets of equipment run into the well at different times. For example, a liner may be placed in the well and a cementing assembly may be run into the well to perform cementing of the liner. Once cementing of the liner is completed the work string with the cementing assembly is typically removed from the well and screens run into the well. Thus, multiple trips into the well have typically been required to place the liner and the screen within the well and to cement the liner and activate the compliant screen. Each trip into the well to position equipment or perform an operation requires additional time and expense. Further the screen assembly will need to have a smaller diameter to enable it to be run through the liner, which can lead to a restriction on the productive capacity of the well and induce constraints on future intervention operations. 
     The one trip liner conveyed screen system of the present disclosure provides an apparatus for selectively providing flow paths through a single work string for screen positioning and screen setting, liner placement and cementing, circulation paths for cleaning and, if desired, activating annular barriers. The flow path selection can be provided by sliding seals, sleeves, or ports formed between the work string and the liner/screen assembly. The selection of the flow path can be made by lifting and lowering the work string relative to the liner/screen assembly and/or by varying the fluid pressure within the work string. The movement of the work string relative to the liner/screen assembly can be performed at the surface location of the well by lifting and lowering the work string. Alternate means for selecting flow paths can also be used. The one trip liner conveyed screen system of the present disclosure provides for the screen to have a larger diameter than a screen assembly that is required if it were to be run through the liner. 
       FIG. 1  is a schematic illustration of an offshore oil and gas platform and the drilling of a wellbore through an oil and gas formation and is generally designated  10 . A semi-submersible platform  12  is located over a submerged hydrocarbon formation  14  located below the sea floor  16 . A subsea conduit  18  extends from the deck  20  of platform  12  to a wellhead installation  22  that includes blowout preventers  24 . Platform  12  has a hoisting apparatus  26  and a derrick  28  for raising and lowering pipe strings, such as a substantially tubular, longitudinally extending drill string or work string. 
     Although  FIG. 1  depicts an offshore slanted well from a semi-submersible platform, it should be understood that the open hole completion operations of the present disclosure are equally well-suited for use on onshore wells or alternative type offshore wells, in vertical wells, horizontal wells, multilateral wells and the like. 
     A wellbore  32  extends through the various earth strata including formation  14 . A casing  34  is shown cemented within a vertical section of wellbore  32  by cement  36 . A drill string  30  extends from the deck  20  of platform  12 , through the wellhead installation  22 , including blowout preventers  24 , and has a drill bit  38  on the distal end. The open hole section  40  extends the wellbore  32  below the casing  34  and through formation  14 . 
       FIG. 2  is an elevation view of a cross-section of an example of a subterranean formation and drilling, completion or workover rig in which a sand control operation may be performed in accordance with certain embodiments of the present disclosure.  FIG. 2  shows a well  100  during a sand control operation adjacent a portion of a subterranean formation of interest  102  surrounding a well bore  104 . The well bore  104  extends from the surface  106 . Although shown as vertical deviating to horizontal, the well bore  104  may include horizontal, vertical, slant, curved, and other types of well bore geometries and orientations, and the sand control operation may be applied to a subterranean zone surrounding any portion of the well bore. The well bore  104  can include a casing  110  that is cemented or otherwise secured to the well bore wall. The well bore  104  can be uncased or include uncased sections. 
     The well is shown with a work string  112  descending from the surface  106  into the well bore  104 . A screen  120  is located on the distal end of the working string  112  and is shown with an upper liner hanger packer  122  and a lower open hole packer  124  which define an annulus area  126  between the screen  120  and the formation  102 . The working string  112  may include coiled tubing, jointed pipe, and/or other structures that allow fluid to flow into the well bore  104  or formation  102 . The working string  112  can include flow control devices, bypass valves, ports, and or other tools or well devices that control a flow of fluid from the interior of the working string  112  into the annulus area between the two packers and screen  120  and the formation  102 . For example, the working string  112  may include ports to communicate a fluid  128  into the annulus area between the two packers and the well bore  104  and out into the formation  102  in the annulus area  126 . 
       FIGS. 3 a  through 3 d    illustrate an embodiment of the present disclosure positioned in a well bore  210  extending from a surface location, not shown, to a bottom hole location  212 . A casing  214  has been placed in an upper portion of the well  210  and the annulus between the casing  214  and well  210  has been filled with cement  216 . Casing  214  may be nominal nine and five/eighth inch steel casing. Below the bottom of the casing  214  or casing shoe  218 , the well  210  remains in an open hole, i.e. uncased, condition. In many cases, the casing  214  is placed in an upper portion of well  210  and the open hole portion of the well  210  includes slanted, curved or otherwise deviated portions so that at the bottom hole location  212 , the well is horizontal or near horizontal. The present disclosure is suitable for use in wells which are vertical to the bottom hole location  212  or which are slanted or deviated or horizontal over portions of their length. 
     An assembly  220  according to the present disclosure is shown positioned in the well  210  extending from the casing  214  down to the bottom hole location  212 . The assembly  220  has been lowered into position on a work string  222  extending from the surface location of the well  210 . A work string for purposes of the present disclosure may be any known pipe having the necessary strength and size to be lowered into and removed from a well  210  to position equipment in the well, flow materials into or from the well for various known operations, etc. A work string  222  may comprise any suitable oilfield tubular element including drill pipe, production tubing, etc. The work string  222  provides a first flow path  224  inside the work string  222  and a second flow path  226  in the annulus between the work string  222  and the casing  214 . Fluids may be circulated from the surface down path  224  and back up annulus  226  or reverse circulated down annulus  226  and back up the path  224 . 
     The assembly  220  includes an outer assembly  228  and an inner assembly  230 . Inner assembly  230  is connected to the lower end of work string  222  throughout its use in the present disclosure so that it is run into the well  210  on the work string  222  and removed from the well  210  with the work string  222 . The inner assembly may therefore be considered part of the work string  222 . The outer assembly  228  is mechanically coupled to the inner assembly when the inner assembly  230  is run into the well  210 , but, as explained below, is thereafter mechanically coupled to the casing  214  and disconnected from the inner assembly  230 , allowing the inner assembly  230  to be repositioned relative to the outer assembly  228  by movements of the work string  222  from the surface location of the well  210 . 
     The outer assembly includes a packer  232 , which is shown inflated into sealing contact with the casing  214 . Packer  232  may be a combination packer hanger to resist axial movement of the outer assembly  228  in the well  210 , or may be only a hanger. In an embodiment, the packer  232  provides a fluid tight seal between outer assembly  228  and the casing  214  as well as mechanically coupling the outer assembly  228  to the casing  214 . Below the packer  232  is located an upper cementing port  234  including a sleeve valve  236  allowing the port  234  to be selectively opened or closed. In the run in position, the valve  236  is closed. Below port  234  is located a length of blank pipe  238 . Blank pipe  238  is a conventional oil field tubular element, for example steel pipe and may be referred to as a liner because a portion of it may be positioned within the casing  214 . In this embodiment, pipe  238  may have a nominal diameter of seven inches and a weight of twenty-three pounds per foot. The length of pipe  238  may be selected based on the distance from the casing shoe  218  to the producing formation or the required position of screens. The pipe  238  will typically pass through curved or deviated portions of the well  210  and may be of considerable length. The various other elements comprising the outer assembly  228  are connected together by various other sections of pipe  238  and/or collars, etc. In some applications, for example in a shallow well, it may be desirable for the pipe  238  to extend a considerable distance up the well  210  and possibly to the surface location and pipe  238  may replace the casing  214 . 
     Below pipe  238  is located a seal bore  240  having an inner sealing surface  242 . In this embodiment, the seal bore  240  may comprise a thick wall coupling or length of pipe having a polished inner seal bore surface  242  having a precise inner diameter, e.g. five inches, which is less than the minimum inner diameter of the pipe  238 . Alternatively, the seal bore  240 , and other seal bores used in the present disclosure, may be a coupling or length of pipe having an inner sealing surface  242  formed of an elastomeric material, e.g. one or more O-rings. As described in more detail below, the inner assembly  230  may carry an outer seal body to seal with the sealing surface  242 . If the sealing surface  242  is a polished metal surface, the inner assembly may carry a matching elastomeric seal body. If the sealing surface  242  comprises an elastomeric element, then, the inner assembly may carry a matching polished metal seal body. 
     Below seal bore  240  is located a lower cementing port  244  including a sleeve valve  246  allowing the port  244  to be selectively opened or closed. In the run in position, the valve  246  is closed. The lower cementing port  244  can also include a spring biased one-way valve, i.e. check valve, which allows fluids to flow out of the port  244  into the annulus  248 , but blocks flow of fluids from the annulus  248  into the port  244 . Other forms of flow direction biased one-way valves may be used if desired. Such a valve may be omitted if desired and may provide no benefit in some situations, for example if the entire interval to be cemented is horizontal. A second seal bore  250  is located below the port  244 . 
     An external casing packer  252  is located below the second seal bore  250 . Below the packer  252  is located a third seal bore  254 . Below seal bore  254  is located a valved port  256 . The valved port  256  includes a sleeve valve  258 , which is typically in its open position when the assembly  220  is run in the well. The valved port  256  can include an outer shroud  260 , which directs fluids flowing out of valved port  256  down hole to avoid erosion of the wall of borehole  210 . A fourth seal bore  262  is positioned below the valved port  256 . Below the seal bore  262  is located a flapper valve  264 . While a flapper valve  264  is used in this embodiment, other fluid loss control devices, e.g. a ball valve, may be used if desired. 
     A screen assembly  266  is located below the flapper valve  264 . The screen assembly includes a screen  268  that may be any conventional or premium screen or compliant screen. Other forms of filters, such as slotted pipe or perforated pipe, may be used in place of screen  268  if desired. Above screen  268 , a length of blank pipe  270  connects the screen  268  to the upper portions of the outer assembly  228 . The pipe  270  may be of smaller diameter than the liner  238 , as illustrated. In some embodiments, the pipe  270  and base pipe used in the screen  268  may be of the same diameter as the liner  238 . In alternate embodiments, the pipe  270  and base pipe used in the screen  268  may be have a larger diameter as the blank pipe  238 . 
     The inner assembly  230  includes a packer setting tool  272  at its upper end connected to work string  222 . The tool  272  is used to set the packer  232  and to release the outer assembly  228  from the work string  222  once the packer  232  is set. The inner assembly includes shifters, e.g.  274 , for opening and closing the sleeve valves  236 ,  246  and  258  as the inner assembly  230  is moved down and up in the well  210 . The inner assembly  230  includes a crossover assembly shown generally at  276 . The crossover  276  includes a port  278  in fluid communication with the flow path  224  through work string  222 . It also includes a flow path  280  in fluid communication with the flow path  226  above packer  232 . 
     On a cylindrical outer surface of crossover  276  is carried a seal unit or seal body  282  extending above and below the port  278 . The seal unit  282  may be formed as a separate metal sleeve having a plurality of elastomeric rings on its outer surface. The outer diameter of the elastomeric rings may be slightly greater, e.g. 0.010 to 0.025 inch greater, than the inner diameter of the seal bores  240 ,  250 ,  254  and  262 . In this embodiment, the seal bores  240 ,  250 ,  254  and  262  have polished metal inner surfaces, e.g.  242 , with which such elastomeric rings may form fluid tight seals. In an alternative discussed above, the inner surfaces of seal bores  240 ,  250 ,  254  and  262  are formed by elastomeric elements such as O-rings. In this alternative, the seal body  282  may comprise only a metal sleeve having a polished outer surface having an outer diameter somewhat larger than the inner diameter of the elastomeric elements forming the inner sealing surfaces, e.g.  242 , of the seal bores  240 ,  250 ,  254  and  262 . In either case, the seal body  282  may form fluid tight seals with the seal bores  240 ,  250 ,  254  and  262  at any point along the length of the seal body  282 . The seal body  282  has sufficient length above and below the port  278  to form seals with seal bores  240  and  250  at the same time and with seal bores  254  and  262  at the same time. 
     The lowermost portion of the inner assembly  230  can comprise a wash pipe  284  which extends through flapper  264  and into the screen  268 . 
     In  FIGS. 3 a -3 d   , the assembly  220  is shown in its run in position in well  210  and with the packer  232  set. The packer  232  was set by dropping a ball  286  down the work string  222 . Before the ball  286  is dropped, the assembly  220  allows full fluid circulation in the well as the work string  222  and assembly  220  are run into the well. The packer setting tool  272  and pressure in the flow path  224  may be used to set the packer  232 . After the packer  232  has been set, the well may be pressure tested by increasing pressure in the annulus  226 . 
     In the run in position shown in  FIG. 3 , the cross over port  278  is located at the lowermost seal bore  262  below the valved port  256 . The seal body  282  contacts the seal bore  262  both above and below port  278 , blocking all flow into or out of the port  278 . Once the ball  286  is in place, the flow path  224  is isolated from the annulus  248  and annulus  226 . After pressure testing the packer  232 , the pressure in the annulus  226  may be increased to set packer  252 , as illustrated in  FIGS. 4-8 . 
     The use of the apparatus of  FIGS. 3 a -3 d    will be described with reference to  FIGS. 4-8 . After the packers  232  and  252  have been set, as shown in  FIG. 4 , the inner string  230  may be repositioned for activating the complaint screen and/or treating a portion of the well  210 . By lifting the work string  222 , the cross over port  278  may be positioned in fluid communication with the valved port  256 . This is achieved by positioning seal body  282  to contact the seal bores  254  and  262  above and below crossover port  278  respectively. A treatment fluid  288 , such as an acid treatment, may then be flowed from the surface down work string  222  and through port  278  and valved port  256  into the annulus  290  adjacent the screen  268 . The displaced liquid flows up the wash pipe  284 , through crossover path  280  and into the annulus  226  which can then flow back to the surface location of well  210 . Then, by closing a device described in the  FIG. 16-20  at the bottom of the compliant screen  268 , pressure can be applied from annulus  226  through crossover path  280 , down the wash pipe  284  inside the compliant screen  268 . The complaint screen  268  will be activated to conform with the borehole geometry. 
     In the  FIG. 4  configuration, the present disclosure may be used to perform pressurized treatments. In some cases it may be desirable to perform a pressurized treatment such as acidizing which requires flowing a fluid down the work string  222  and into the formation surrounding the screen  268 . In the  FIG. 4  configuration, any treating fluid may be flowed down the work string  222  and pumped into the annulus  290  around the screen  268 . By blocking return flow through the annulus  226 , pressure may be applied to force the fluid into the formation surrounding the screen  268 . The present disclosure provides a convenient system for selectively treating the production zone surrounding the screen  268 . 
     In  FIG. 5 , the work string  222  has again been lifted to move the cross over port  278  above the seal bore  254  while leaving the seal body  282  in sealing contact with the seal bore  254  below port  278 . In this position, fluid may be reverse circulated down the annulus  226 , into crossover port  278  and up the work string  222  to remove any remaining treating fluid from the annulus  226  and work string  222 . 
     In  FIG. 6 , the work string  222  has been moved into position for cementing the pipe  238  above the packer  252 . The work string  222  has been first lifted to position sleeve shifters above the sleeve valves  236  and  246 . During this lifting operation, another shifter can move the sleeve  258  to close the valved port  256  to ensure that no cement can get below the valved port  256  and possibly plug or otherwise harm the screen  268  function. The work string  222  is then lowered to the position shown in  FIG. 6 . As it is lowered, shifters open the sleeve valves  236  and  246  in the upper and lower cementing ports  234  and  244 . In this cementing position, the crossover port  278  is in fluid communication with the lower cementing port  244 . The seal body  282  makes sealing contact with the seal bores  240  and  250 , above and below the crossover port  278  respectively. In this position, cement  294  may be flowed down the work string  222 , through crossover port  278  and lower cementing port  244  into the annulus  248 . The cement  294  will then flow up the annulus  248  towards the upper cementing port. In this embodiment, the lower cementing port  244  includes a spring biased check valve. The spring bias may be adjusted to set a minimum pressure at which cement can be pumped through the valve and to provide positive closing of the check valve when pumping has stopped. It may be desirable to pump only enough cement to fill the annulus  248  up to about the location of the casing shoe  218 , which is below the port  234 . If excess cement is pumped, the excess may flow into the casing  214 , through port  234  and back up the annulus  226 . In some applications, e.g. shallow wells mentioned above, the blank pipe may extend a considerable distance up the well  210  and may replace casing  214 . In such applications, the cementing operation may extend over the length of the pipe  238  and possibly to the surface location of the well and the upper cementing port  234  and packer  232  may be omitted. Reservoir isolation has been provided prior to the cementing operation by means of mechanically closing the valved port  256  that in this embodiment functions as a fluid loss control device positioned above the screen. 
     After pumping of cement  294  is stopped, the work string  222  is again lifted a short distance to the position shown in  FIG. 7 . In this position, the cross over port  278  is positioned above the seal bore  240  and the seal body  282  below port  278  forms a seal with seal bore  240 . Clean fluid may then be circulated down work string  222 , through the port  278  and back up the annulus  226  to clean out any excess cement. If desired, the circulation may be reversed. The lower cementing port  244  includes a spring loaded check valve, which closes when the pumping of cement stops. The check valve prevents flow of cement back into the lower cementing port  244  while the work string  222  is being cleaned. 
     In this embodiment, the cementing operation is performed after the activation of the compliant screen and treatment operation. However, if desired the apparatus may be employed to selectively cement first and then perform the treatment operation and activate the compliant screen. In either case, only one trip into the well is required. In completions with multiple screens as discussed below, it may be desirable to cement around blank pipe sections between screens. In that situation, the cementing and treatment operations may be performed alternately, i.e. compliant screen activation, followed by cementing, followed by treatment, etc. 
     After the cement has been placed as shown in  FIGS. 6 and 7 , and the well and work string have been cleaned out as shown in  FIG. 7 , the work string  222  and the inner assembly  230  may be removed completely from the well. As the inner assembly  230  is removed, shifters close the valves  236  and  246 . As the inner assembly  230  is lifted, the wash pipe  284  is removed from the screen  268  and the flapper valve  264  closes as shown in  FIG. 8 . If another type of fluid loss control device is used, e.g. a ball valve, a shifter may be used to close the valve. The valve  264  may be a ceramic flapper valve, or other type of fluid loss control device that may be opened or removed for production by methods known in the art. As noted above, the movements of the work string  222  have closed all three of the sleeve valves  236 ,  246  and  258  so that all ports in the outer assembly are closed and all produced fluids must flow through the screen  268 . 
     In this  FIG. 8  configuration, pipe  238  and screen  268  which can be a compliant screen, have been properly installed in an open-hole well  210  with a single trip into the well. The well has been treated, compliant screen  268  has been actuated and placed in a production mode and the blank pipe  238  has been cemented without removing and/or replacing a work string or any part of a work string. The only surface operations required are relatively small vertical repositioning, such as lifting and lowering the work string, the pressuring up or down of the work string, and flowing of appropriate cement and clean out fluids. In certain embodiments other actuation methods can be employed, such as by electrical/accoustic signals or pressure cycle or timer or pressure hydrostatic pressure or activating balls or wiper plugs or any combination of these different activation methods that can shift ports or make other mechanical changes within the work string or within the liner/screen assembly or float shoe assembly. 
     In  FIG. 9  is shown an embodiment wherein the pipe  238  and compliant screen  268  have been properly installed in an open-hole well  210  with a single trip into the well. The compliant screen  268  has been actuated and placed in a production mode and the blank pipe  238  has been cemented without removing and/or replacing a work string or any part of a work string. In this embodiment the liner  238  and blank pipe  270  can be of the same size. The compliant screen  268  once actuated will be of a larger diameter than that of the liner  238  and blank pipe  270  as shown in  FIG. 9 . 
       FIG. 10  illustrates a service tool  350  that can be used with the embodiment of the assembly shown in  FIG. 9 . The service tool can include a base pipe  352  and a liner hanger  354 . The service tool  350  further includes one or more circulation ports  356 , one or more seal assemblies  358 , a cross-over port  360 , a ball seat  362 , a MCS shifter  364 , a reduced diameter extension  366  and a fluid loss device FLD shifter  368 . The assembly  220  also includes a downhole shutoff collar  269  and a float shoe assembly  271 . 
       FIGS. 11 a  through 11 f    show cross-sectional views and sectional views of a compliant screen assembly  300  according to an embodiment, at its Run-in state  302 , Activation state  304 , and Production state  306 . At the run-in state  302  the compliant screen  310  is compressed against a base pipe  312  and the assembly has an open flow path  314  therethrough. Fluid flow can be circulated through the assembly  300  if needed to wash down through the wellbore to get to the desired setting depth. The screen assembly  300  can be run in the well with the liner in a single trip on a work string. Pressure can be applied to the work string to set the top hanger packer, release the running tool, set the open hole isolation packers (if hydraulic isolation packer is used) and to put the screen in the activation state  304 . Pressure can be bled off and then re-applied to extend the screen  310  to the borehole wall. During the activation state  304  fluid flow through the bottom of the assembly  300  is blocked and hydraulic pressure applied to the assembly  300  can expand the internal chambers  316  and expand the screen  310 . In an embodiment, the activated screen  310  can be conformed to the wellbore wall to stabilize and provide support to the wellbore wall. With the screen  310  activated and the pressure bled off, the assembly will convert to the production state  306  to allow fluid production from the formation, through the activated screen  310  and the base pipe  312 , through the liner and into the cased wellbore/production tubulars. In an embodiment the compliant screen assembly  300  can be the Endurance Hydraulic Screen® screen assembly available from Halliburton of Houston Tex. Although the Endurance Hydraulic Screen® screen assembly is shown and described herein, other versions of compliant screen systems can be used within the scope of this disclosure. 
     To activate the compliant screen assembly  300  the bottom end of the screen assembly  318  will typically need to be isolated. Several options are available to seal off the bottom of the screen assembly, including a simple bull plug. A downhole shutoff collar as shown in  FIG. 13  can be used.  FIGS. 13 a  and 13 b    illustrate a downhole shutoff collar that can be run at the end of the screen assembly. The downhole shutoff collar provides a fluid flow path for washing down the assembly with the ability to be shut off and seal the end of the assembly so that hydraulic pressure can be applied to activate the screen. The downhole shutoff collar coupled with a double sideport float shoe  271  as shown in  FIG. 14  will allow circulation/washdown while running the assembly into the well. A ball can be dropped from the surface to actuate the shut off and isolate the float shoe  271 . It will provide a liner/screen assembly pressure seal enabling the setting of the packers and the activation of the compliant screen. 
       FIGS. 12 a  through 12 d    show cross-sectional views of an expandable screen assembly  300  according to an embodiment. A screen element  310  is shown in  FIG. 12A  on the exterior of a base pipe  312 , the base pipe defining a passageway  314 . In  FIG. 12B  is shown a screen element  310  in a collapsed position, the screen forming a flattened cavity  311 . The base pipe  312  contains passageways  313  that allow a fluid flow as shown by arrows  317  to enter and pressure up the cavity  311 . With fluid flow  315  the pressure in the cavity  311  increases and expands the screen element  310  as in shown in  FIG. 12C . Once the screen  310  is expanded the screen assembly  300  can be put into a production mode as shown in  FIG. 12D  where fluid flow  315  from the screen  310  flows through the passageways  313  and is flow  319  within the base pipe  312 . Many alternate expandable screen assemblies are available and are not limiting as to the application to the disclosure herein. 
       FIGS. 13 a - b    illustrates an elevation view of a downhole shutoff collar assembly  269  according to an embodiment that can be run at the end of the screen assembly. The shutoff collar assembly  269  provides a fluid flow path for washing down the screen assembly that can be used to facilitate the one trip method disclosed herein. 
       FIG. 14  illustrates an elevation view of a double sideport float shoe assembly  271  according to an embodiment that can be run at the end of the screen assembly. The float shoe  271  provides a fluid flow path for washing down the screen assembly that can be used to facilitate the one trip method disclosed herein. 
       FIGS. 15 a - b    illustrate a dart and a wiper plug attached to a liner hanger setting tool that can be used to facilitate the one trip method. A wiper plug and landing collar could be used to isolate the float shoe assembly  271 . A dart can be dropped from the surface to land on the wiper plug assembly in the hanger setting tool. Pressure can be applied to expend the wiper plug assembly to the bottom landing collar as shown in  FIG. 15 . The float shoe  21  will be isolated enabling pressure to be applied to set the hanger/packers and activate the screen assembly. 
       FIG. 16  illustrates a landing collar with double sideport float shoe assembly  271  that can be used to facilitate the one trip method disclosed herein. 
       FIG. 17  illustrates an elevation view of an eRED plug assembly according to an embodiment available from Halliburton of Houston Tex. The eRED® plug assembly contains an electronic activation element that can be actuated by a signal such as a pressure or temperature change, a timer, or other signal. The eRED® plug combined with a double sideport float shoe  271  can enable the circulation of fluids down through the shoe  271  while running in the hole. The eRED® can then be triggered to close (possible trigger: hydrostatic pressure or timer or applied pressure or combination thereof), isolate the float shoe  271  and allow pressure to be applied to set the hanger/packers and activate the screen. 
     The above operational procedures are meant to be non-limiting examples of a procedure that could be employed to achieve the desired results of the discloser herein. Alternate procedures may also be employed to likewise achieve the desired results of the discloser herein. 
     In some cases the liner may not need to be cemented in place, which can be accommodated by the setting of two packers on either end of the liner. These may be pressure activated or chemically activated annular barriers. If the liner requires cementing the work string and service tool can be picked up to open the return flow circulation device and place the service tool into the backflow circulating device above the open hole packer to circulate cement around the liner. 
     This system provides a sand control solution in a single trip with an intermediate liner while keeping the capability of isolating or/and cementing the liner if desired. This system provides a sand control solution without necessarily having to perform a gravel pack with a considerable reduction of operational risk and cost. Such method will also generally reduce rig time and the related overall cost of well construction and completion. 
     An embodiment of the present disclosure is a method for placing a compliant screen and liner in a well in a single trip. The method includes running into the well a work string having a liner and a compliant screen assembly and positioning the compliant screen assembly and liner within the well. The method can further include cementing the liner within the well without removing the work string from the well between cementing and positioning the liner and compliant screen assembly. The method can further include actuating a compliant screen assembly and extending an expandable element of the screen assembly without removing the work string from the well between positioning and actuating the screen assembly. The disclosed method enables a larger bore screen to be run in the open hole that otherwise would be limited by the ID of the liner. 
     An embodiment of the present disclosure is an apparatus for one trip completion of a well that includes a screen assembly carried on a work string, a liner carried on the work string, the compliant screen assembly and liner operable in response to positioning of the work string in the well and/or pressure within the work string without removal of the work string from the well. The apparatus can include cementing equipment carried on the work string, the cementing equipment selectively operable in response to positioning of the work string in the well and/or pressure within the work string without removal of the work string from the well. The apparatus can include compliant screen assembly activation equipment carried on the work string, the activation equipment selectively operable in response to positioning of the work string in the well and/or pressure within the work string to radially extend a screen without removal of the work string from the well. 
     In another embodiment having multiple screen assemblies, the assemblies may be connected by lengths of blank pipe. It may be desirable to block annular flow outside the lengths of blank pipe by, for example, open hole packers and/or cementing the annuli around such lengths of blank pipe. Cementing of such multiple lengths of pipe between multiple screen assemblies may be accomplished by providing upper and lower cementing ports and seal bores for each length of pipe which is to be cemented. The inner assembly may then be positioned to selectively open cementing valves and flow cement into the various annuli between the blank pipe lengths and the well bore wall. 
     An embodiment of the present disclosure is a method for completing a well in a single trip, that includes running into the well a liner, a liner hanger, at least one open-hole packer, a compliant screen assembly and float shoe on a work string. The method includes positioning the liner, liner hanger, at least one open-hole packer, compliant screen assembly and float shoe within the well while washing down through the float shoe, setting the liner hanger and the at least one open-hole packer and placing the compliant screen assembly in production mode without removing the work string from the well between setting the liner hanger and at least one open-hole packer and placing the screen assembly in production mode. 
     The method can include isolating an annulus between the liner and the well by cementing the liner within the well without removing the work string from the well between cementing the liner and positioning the compliant screen assembly. The method can optionally include isolating an annulus between the liner and the well by annular barrier device without removing the work string from the well between isolating the annulus between the liner and the well and positioning the compliant screen assembly. Alternate embodiments include actuating the compliant screen assembly and extending an expandable element of the screen assembly without removing the work string from the well between positioning and actuating the screen assembly. In an embodiment the expanded screen element conforms to the wall of the well, thus providing formation stabilization as well as filtering effects. They can further include setting a portion of the liner within a cased portion of the well. 
     An alternate embodiment includes running into the well a work string comprising a plurality of liner sections and screen sections and positioning the plurality of compliant screen sections and liner sections within the well. The individual annulus between each liner section and wellbore can be isolated either by an annular barrier device or by cementing the liner within the well without removing the work string from the well between cementing each liner section and positioning the plurality of compliant screen sections. 
     An alternate embodiment is a single trip completion of a well in an open hole that includes running a work string into the well, using the work string to position a liner, a liner hanger, at least one open-hole packer, a compliant screen assembly and a float shoe while circulating through the float shoe. Once positioned the completion includes setting the liner hanger and at least one open-hole packer, actuating the compliant screen assembly and placing the compliant screen assembly in production mode. Then the at least a portion of the work string is repositioned to activate a cementing functionality of the work string. The workstring is used to isolate an annulus between the liner and the well without removing the work string from the well between the cementing operation and placing the compliant screen assembly in production mode. The annulus between the liner and well can be isolated by cementing the liner within the well or by setting one or more annular barrier device. The method can further include actuating the compliant screen assembly and extending an expandable element of the compliant screen assembly without removing the work string from the well between positioning and actuating the compliant screen assembly. The liner can be set within a cased portion of the well. 
     Alternate embodiments can include running into the well a work string comprising a plurality of liner sections and compliant screen sections and positioning the plurality of compliant screen sections and liner sections within the well, which can further include isolating the individual annulus between each liner section and wellbore either by annular barrier device or cementing the liner within the well without removing the work string from the well between cementing each liner section and positioning the plurality of compliant screen sections. 
     A further embodiment is an apparatus for one trip completion of a well that includes a compliant screen assembly, liner and cementing equipment carried on a work string. The compliant screen assembly, liner and cementing equipment selectively operable in response to positioning of portions of the work string in the well and/or pressure within the work string without removal of the work string from the well. The apparatus can include compliant screen assembly activation equipment carried on the work string, the activation equipment selectively operable in response to positioning of the work string in the well and/or pressure within the work string to radially extend a screen without removal of the work string from the well. The apparatus can include a plurality of liner sections and compliant screen sections, and can optionally include sufficient ports and sleeves for isolating each individual annulus between each liner section and wellbore either by annular barrier device or cementing the liner within the well without removing the work string from the well between cementing each liner section and positioning the plurality of compliant screen sections. 
     The operations of the steps are described with reference to the systems/apparatus shown described herein. However, it should be understood that the operations of the steps could be performed by embodiments of systems and apparatus other than those discussed herein and are not meant to be limiting. Embodiments discussed herein could perform alternate operations different than those discussed but achieving substantially similar results. 
     The text above describes one or more specific embodiments of a broader disclosure. The disclosure also is carried out in a variety of alternate embodiments and thus is not limited to those described here. The foregoing description of an embodiment of the disclosure has been presented for the purposes of illustration and description. It is not intended to be exhaustive or to limit the disclosure to the precise form disclosed. Many modifications and variations are possible in light of the above teaching. It is intended that the scope of the disclosure be limited not by this detailed description, but rather by the claims appended hereto.