Patent Publication Number: US-11047211-B2

Title: Reverse circulation debris removal tool for setting isolation seal assembly

Description:
PRIORITY 
     The present application is a U.S. National Stage patent application of International Patent Application No. PCT/US2016/056130, filed on Oct. 7, 2016, the benefit of which is claimed and the disclosure of which is incorporated herein by reference in its entirety. 
     TECHNICAL FIELD 
     The present disclosure generally relates to oilfield equipment and, in particular, to installation of completion equipment once a wellbore has been drilled. More particularly still, the present disclosure relates to systems and methods for removing debris accumulated about lower completion equipment while at the same time installing upper completion equipment. 
     BACKGROUND 
     After drilling the various sections of a subterranean wellbore that traverses a formation, a completion assembly is often installed to enhance and optimize production of hydrocarbons from the wellbore. Generally, completion assemblies may include sealing elements, mechanical filtering elements and flow control elements. More particularly, completion assemblies often comprise both a lower completion assembly and an upper completion assembly. Typically, the lower completion assembly is installed and used to isolate and control production zones, in the lower portion of the wellbore from upper portions of the wellbore. At the upper end of the lower completion assembly, above the lower completion assembly&#39;s isolation barrier valve, is a closing sleeve and packer assembly. Following installation of the lower completion assembly, an isolation seal assembly is run-in and installed to isolate the closing sleeve and to enable the lower completion assembly to be engaged by the upper completion assembly. Finally, an upper completion assembly is run-in and engaged with the lower completion assembly. The upper completion assembly often includes a production packer, fluid monitoring and control devices and a safety valve barrier assembly. 
     Following installation of the lower completion assembly but prior to run-in of the isolation seal assembly, one practice is to run in debris extraction equipment into the wellbore to remove gravel, sands, shavings and other debris that may have accumulated in the wellbore above the top of the lower completion assembly. Such debris extraction equipment may include tubing with fluid jets that vent into the wellbore annulus to create a reverse circulation flow that results in a low pressure suction to pull debris into the inner annulus of the tubing. It is highly desirable to clean the upper end of the lower completion assembly in order to ensure that debris does not interfere with engagement of the isolation seal assembly to the lower completion assembly or engagement of the upper completion assembly to the isolation seal assembly. Thus, in order to most effectively install an upper completion assembly in a wellbore, multiple trips into the wellbore are required. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         FIG. 1  depicts an offshore well completion system having an isolation seal assembly installed using reverse circulation debris removal tool, according to one or more illustrative embodiments; 
         FIG. 2  depicts a reverse circulation debris removal tool during installation of the isolation seal assembly of  FIG. 1 , according to one or more illustrative embodiments. 
         FIG. 3  depicts an isolation seal assembly, according to certain illustrative embodiments of the present disclosure. 
         FIGS. 4A-4B  depict an isolation seal assembly carried by a debris removal tool and engaged with a lower completion assembly, according to certain illustrative embodiments of the present disclosure. 
         FIGS. 5A-5B  depicts working fluid flow during debris removal utilizing the assembly of  FIG. 5 , according to certain illustrative embodiments of the present disclosure. 
         FIG. 6  is a method for deploying an isolation seal assembly utilizing a reverse circulation debris removal tool, according to certain illustrative embodiments of the present disclosure. 
     
    
    
     DESCRIPTION OF ILLUSTRATIVE EMBODIMENTS 
     The disclosure may repeat reference numerals and/or letters in the various examples or figures. This repetition is for the purpose of simplicity and clarity and does not in itself dictate a relationship between the various embodiments and/or configurations discussed. Further, spatially relative terms, such as beneath, below, lower, above, upper, uphole, downhole, upstream, downstream, and the like, may be used herein for ease of description to describe one element or feature&#39;s relationship to another element(s) or feature(s) as illustrated, the upward direction being toward the top of the corresponding figure and the downward direction being toward the bottom of the corresponding figure, the uphole direction being toward the surface of the wellbore, the downhole direction being toward the toe of the wellbore. Unless otherwise stated, the spatially relative terms are intended to encompass different orientations of the apparatus in use or operation in addition to the orientation depicted in the figures. For example, if an apparatus in the figures is turned over, elements described as being “below” or “beneath” other elements or features would then be oriented “above” the other elements or features. Thus, the exemplary term “below” can encompass both an orientation of above and below. The apparatus may be otherwise oriented (rotated 90 degrees or at other orientations) and the spatially relative descriptors used herein may likewise be interpreted accordingly. 
     Moreover, even though a figure may depict a horizontal wellbore or a vertical wellbore, unless indicated otherwise, it should be understood by those skilled in the art that the apparatus according to the present disclosure is equally well-suited for use in wellbores having other orientations including, deviated wellbores, multilateral wellbores, or the like. Likewise, unless otherwise noted, even though a figure may depict an offshore operation, it should be understood by those skilled in the art that the apparatus according to the present disclosure is equally well-suited for use in onshore operations and vice-versa. 
     Generally, illustrative embodiments and related methods are described below as they might be employed in an anchor assembly, such as an isolation seal assembly, that may be carried by a debris removal tool during run in of the debris removal tool. The isolation seal assembly generally includes an elongated tubular with a first end and a second with a releasable engagement mechanism at the first end for releasably securing the isolation seal assembly to a debris removal tool. A first set of seals are externally mounted along the tubular. Perforations or slots are provided along the elongated tubular between the engagement mechanism and the first set of seals. A latch mechanism may be provided adjacent the first end of the tubular for engaging the lower end of an upper completion string. Another latch mechanism may be provided between the first set of seals and the perforations for engaging the upper end of a lower completion string. A second set of seals may be externally mounted along the tubular adjacent the second end of the tubular. The engagement mechanism and the latch mechanism adjacent the first end may be the same. The isolation seal assembly is attached to a debris removal tool and thus, can be run-in and set at the same time the debris removal tool is run-in. In one or more embodiments, when the isolation seal assembly is secured to the debris removal tool by the engagement mechanism, the snorkel of the debris removal tool extends beyond the second end of the elongated tubular of the isolation seal assembly to allow operation of the debris removal tool while the isolation seal assembly is attached. The system can be run-in until the lower latch mechanism engages the lower completion assembly. Application of a release force may then be used to separate the debris removal tool from the isolation seal assembly, permitting continued cleaning and thereafter, removal of the debris removal tool. 
     Turning to  FIG. 1 , shown is an elevation view in partial cross-section of a wellbore completion system  10  utilized to complete wells intended to produce hydrocarbons from wellbore  12  extending through various earth strata in an oil and gas formation  14  located below the earth&#39;s surface  16 . Wellbore  12  may be formed of a single or multiple bores, extending into the formation  14 , and disposed in any orientation, such as the horizontal wellbore  12   a  illustrated in  FIG. 1 . 
     Completion system  10  includes a rig or derrick  20 . Rig  20  may include a hoisting apparatus  22 , a travel block  24 , and a swivel  26  for raising and lowering casing, drill pipe, coiled tubing, production tubing, other types of pipe or tubing strings or other types of conveyance vehicles such as wireline, slickline, and the like  30 . In  FIG. 1 , conveyance vehicle  30  is a substantially tubular, axially extending work string or production casing, formed of a plurality of pipe joints coupled together end-to-end supporting a completion assembly as described below. 
     Rig  20  may be located proximate to or spaced apart from wellhead  40 , such as in the case of an offshore arrangement as shown in  FIG. 1 . One or more pressure control devices  42 , such as blowout preventers (BOPs) and other equipment associated with drilling or producing a wellbore may also be provided at wellhead  40  or elsewhere in the system  10 . 
     For offshore operations, as shown in  FIG. 1 , rig  20  may be mounted on an oil or gas platform  44 , such as the offshore platform as illustrated, semi-submersibles, drill ships, and the like (not shown). Although system  10  of  FIG. 1  is illustrated as being a marine-based completion system, system  10  of  FIG. 1  may be deployed on land. In any event, for marine-based systems, one or more subsea conduits or risers  46  extend from deck  50  of platform  44  to a subsea wellhead  40 . Tubing string  30  extends down from rig  20 , through subsea conduit  46  and BOP  42  into wellbore  12 . 
     A working or service fluid source  52 , such as a storage tank or vessel, may supply, via flow lines  64 , a working fluid  54  (see  FIGS. 5A and 5B ) pumped to the upper end of tubing string  30  and flow through tubing string  30  to equipment disposed in wellbore  12 , such as subsurface equipment  56 . Working fluid source  52  may supply any fluid utilized in wellbore operations, including without limitation, drilling fluid, cement slurry, acidizing fluid, liquid water, steam or some other type of fluid. 
     Completion system  10  may generally be characterized as having a pipe system  58 . For purposes of this disclosure, pipe system  58  may include casing, risers, tubing, drill strings, completion or production strings, subs, heads or any other pipes, tubes or equipment that couples or attaches to the foregoing, such as string  30 , conduit  46 , collars, and joints, as well as the wellbore  12  and laterals in which the pipes, casing and strings may be deployed. In this regard, pipe system  58  may include one or more casing strings  60  that may be cemented in wellbore  12 , such as the surface, intermediate and production casings  60  shown in  FIG. 1 . An annulus  62  is formed between the walls of sets of adjacent tubular components, such as concentric casing strings  60  or the exterior of tubing string  30  and the inside wall of wellbore  12  or casing string  60 , as the case may be. 
     Fluids, cuttings and other debris returning to surface  16  from wellbore  12  are directed by a flow line  64  to storage tanks  54  and/or processing systems  66 , such as shakers, centrifuges and the like. 
     As shown in  FIG. 1 , subsurface equipment  56  is illustrated as completion equipment and tubing string  30  in fluid communication with the completion equipment  56  is illustrated as production tubing  30 . Although completion equipment  56  can be disposed in a wellbore  12  of any orientation, for purposes of illustration, completion equipment  56  is shown disposed in a substantially horizontal portion of wellbore  12  and includes a lower completion assembly  82  having various tools such as an orientation and alignment subassembly  84 , a packer  86 , a sand control screen assembly  88 , a packer  90 , a sand control screen assembly  92 , a packer  94 , a sand control screen assembly  96  and a packer  98 . 
     Extending downhole from lower completion assembly  82  is one or more control lines  100 , that pass through packers  86 ,  90 ,  94  and may be operably associated with one or more devices  102  associated with lower completion assembly  82 . Control lines  100  may include hydraulic lines, electric lines, optic lines, etc. Where control lines are electric or optic lines, such as cable devices  102  may be electric or optic devices, such as sensors, positioned dowhnole. Devices  102  may be controllers or actuators used to operate downhole tools or fluid flow control devices. Cable  100  may operate as communication media, to transmit power, or data and the like between lower completion assembly  82  and an upper completion assembly  104 . Data and other information may be communicated using electrical signals, optic signals acoustic signals or other telemetry that can be converted to electrical signals at the rig  20  to, among other things, monitor the conditions of the environment and various tools in lower completion assembly  82  or other tool string. 
     In this regard, disposed in wellbore  12  at the lower end of tubing string  30  is an upper completion assembly  104  that includes various tools such as a packer  106 , an expansion joint  108 , a packer  110 , a fluid flow control module  112 . Additional completion equipment  114  is also illustrated in  FIG. 1 . In one or more embodiments, this additional completion equipment  114  may be a component of or otherwise form part of lower completion assembly  82  or upper completion assembly  104 . In  FIG. 1 , and generally throughout the description, additional completion equipment  114  may be referred to as an anchor assembly  114 , or as an isolation tool assembly  114 , but need not be limited to the specific descriptions os such. In any event, as shown in  FIG. 1 , additional completion equipment  114  is an anchor assembly  114  that generally secures upper completion assembly  104  to lower completion assembly  82 . In one or more embodiments, to the extent lower completion assembly  82  includes a closing sleeve (not shown), anchor assembly  114  may be or include an isolation seal assembly. 
     Extending uphole from upper completion assembly  104  are one or more control lines  116 , such as hydraulic tubing, sensor cable or electric cable, which extends to the surface  16 . Cable  116  may operate as communication media, to transmit power, signals or data and the like between a surface controller (not shown) and the upper and lower completion assemblies  104 ,  82 , respectively. 
     With respect to anchor assembly  114 , the anchor assembly  114  includes openings  120 , such as apertures, perforations or slots, along a portion of the tubular  122  forming anchor assembly  114 . Anchor assembly  114  may further include a latch mechanism  124  for engagement with upper completion assembly  104 . 
       FIG. 2  illustrates the wellbore  12  of  FIG. 1  with a lower completion assembly  82  deployed therein, but without the upper completion assembly  104  of  FIG. 1 . Rather, a debris removal tool  130  is illustrated as it is being lowered on a tubing string  30  into wellbore  12  towards lower completion assembly  82 . Secured to debris removal tool  130  is anchor assembly  114 . Although debris removal tool  130  need not be limited to a particular type of debris removal tool, in some embodiments debris removal tool is a reverse circulation debris removal tool  130  and will generally be described as such herein. In this regard, as shown, debris removal tool  130  generally includes a head  132  from which a snorkel  134  extends. 
     Turning to  FIG. 3 , anchor assembly  114  is illustrated in more detail. Anchor assembly  114  is generally formed of a sub or tubular  122  having a through bore  140  extending between a first end  142  and a second end  144 , the tubular  122  having an inner tubular surface  146  and an outer tubular surface  148 . A first latch mechanism  124  is disposed on tubular  122  adjacent first end  142 . A first seal assembly  152  is positioned along outer tubular surface  148  between first latch mechanism  124  and second end  144  of tubular  122 . Although seal assembly  152  is not limited to a particular type of seal, in one or more embodiments, seal assembly  152  may be an elastomeric element(s)  154  seated in a recess(es)  156  formed in surface  148 , while in other embodiments, seal assembly  152  may include an expandable elastomeric element. One or more perforations or slots  120  are formed along tubular  122  between first latch mechanism  124  and first seal assembly  152 , and extend from inner surface  146  to outer surface  148 . In one or more embodiments, a second latch mechanism  160  may be positioned along tubular  122  between perforations  120  and second end  144 . In embodiments where anchor assembly  114  is to function as an isolation seal assembly, such as is shown in  FIG. 4  below, anchor assembly  114  may further include a second seal assembly  162  positioned along outer tubular surface  148  between first seal assembly  152  and second end  144  of tubular  122 . In one or more embodiments of an isolation seal assembly, tubular  122  may include an elongated tubular portion  164  between the first and second seal assemblies  152 ,  162 , with second seal assembly  162  positioned adjacent second end  144  of tubular  122 . Anchor assembly  114  may also include a releasable engagement mechanism  166  adjacent first end  142  of tubular  122 . In one or more embodiments, engagement mechanism  166  may be a shear mechanism  168 , such as a shear ring, shear bolt or shear pins. In other embodiments, first latch mechanism  124  may form engagement mechanism  166 . Finally, a seal  170  may be positioned along inner surface  146  of tubular  122  adjacent engagement mechanism  166 . 
     With reference to  FIGS. 4 a  and 4 b   , the anchor assembly  114  of  FIG. 3  is shown attached to a reverse circulation debris removal tool  130  and engaging the upper end of a lower completion assembly  82 . Debris removal tool  130  generally includes a tool sub  131  having a head  132  from which a snorkel  134  extends. A suction tip  170  is disposed at the distal end  172  of snorkel  134  with an opening  174  into the interior  176  of snorkel  134 . As shown, when anchor assembly  114  is attached to debris removal tool  130 , snorkel  134  extends beyond the second end  144  of anchor assembly  114 . Sub  131  may also include one or more jet nozzles  178  that vent a working fluid  54  (see  FIGS. 5A and 5B ) from an interior flow passage (not shown) of the tool  130  to the exterior of the tool  130  so that conventional circulation from the surface can be used to induce a reverse circulation loop from the top of the tool to the bottom of the string, creating a low pressure within tool  130  and causing a high velocity, reverse circulation flow effect at the suction tip  174  of snorkel  134 . In preferred embodiments, the length L 1  of the snorkel  134  is selected so that the snorkel  134  extends past the second end  144  of tubular  122  of anchor assembly  114 . Thus, in some embodiments, the length L 1  of the snorkel  134  is longer than the length L 2  of anchor assembly  114 . 
     Although the anchor assembly  114  described herein is not intended to be limited by the particular configuration of lower completion assembly  82  with which it may be used, in one or more embodiments, lower completion assembly  82  may generally include an isolation barrier valve assembly  180  disposed along an internal flowpath  182  of the lower completion assembly  82  for selective opening and closing of the isolation barrier valve assembly  180  and control of fluid flow along flow path  182 . Likewise, lower completion assembly  82  may include a packer assembly  184  deployed between the isolation barrier valve assembly  180  and an end  186  of lower completion assembly  82 . Packer assembly  184  may include a packer sub  188  on which is mounted one or more elastomeric sealing elements  190  and one or more slips  192 . Finally, packer assembly  184  may include a bore  192  defined therein, at least a portion of which defines a sealing surface  194  for receipt of seals  152  of anchor assembly  114 . 
     In one more embodiments, such as is illustrated, lower completion assembly  82  includes a closing sleeve  200  disposed between the isolation valve  180  and the packer assembly  184 . Closing sleeve  200  generally is formed of an elongated tubular  202  having one or more ports  204  defined therein. Tubular  202  include a bore  206  defined therein, at least a portion of which defines a sealing surface  208  for engagement with seals  162  of anchor assembly  114 . As illustrated, when anchor assembly  114  is deployed in lower completion assembly  82  (particularly when latch mechanism  160  is engaged with latch sub  210  as described below), first and second seal assemblies  152 ,  162  are positioned above and below ports  204  of closing sleeve  200  so as to seal ports  204  form communication with flow path  182 . 
     A latch sub  210  may be positioned adjacent packer assembly  184  or otherwise integrally formed therewith. Latch sub  210  includes a latch  212  for engagement with latch mechanism  160  of anchor assembly  114  to permit anchor assembly  114  to be axially and/or radially fixed to lower completion assembly  82 . It will be appreciated that while a latch sub  210  and latch mechanism  160  are illustrated, in other embodiments, these components may be eliminated. Rather, anchor assembly  114  may be allowed to move or “float” relative to lower completion assembly  82  so long as seal assemblies  152 ,  162  seal flow path  182  from fluid communication with annulus  62  (see  FIG. 1 ). 
     In any event, engagement mechanism  166  is releasably attached to head  132  of debris removal tool  130 . Engagement mechanism  166  permits anchor assembly  114  to be secured to debris removal tool  130  during run-in and for purposes of engaging anchor assembly  114  with lower completion assembly  82 , but then selectively detached from debris removal tool  130 . For example, it will be appreciated that once latch mechanism  160  engages latch  212 , an axial or rotational shearing force may be applied to shear mechanism  166  through debris removal tool  130 , causing shear mechanism  166  to shear, thereby releasing debris removal tool  130  from anchor assembly  114 . In other embodiments where a latch sub  210  and/or latch mechanism  160  are not provided and anchor assembly  114  is allowed to float within lower completion assembly  82 , it will be appreciated that other manipulation may be employed to release engagement mechanism  166  from head  132  of debris removal tool  130 . For example, suction tip  170  may be advanced until it seats against isolation barrier valve assembly  180 , after which, a continued downward axial force on debris removal tool  130  will cause shearing of shear element  168  (see  FIG. 3 ) and thus release of anchor assembly  114  from debris removal tool  130 . 
     In one or more embodiments, the distal end  172  of snorkel  134  may include a shift profile  171  disposed for engagement with a shift profile  181  of valve  180 . If needed, these shift profiles  171 ,  181  may be located and engaged to operate the barrier value  180  mechanically using axial force prior to retrieval of the debris removal tool  130 . 
       FIGS. 5 a  and 5 b    illustrates the anchor assembly  114 , debris removal tool  130  and lower completion assembly  82  of  FIG. 4 , but deployed in a wellbore  12 . In particular, the anchor assembly  114  carried by debris removal tool  130  is stabbed into or otherwise engaged with the lower completion assembly  82  so that the through bore  140  of the isolation seal assembly  114  is in fluid communication with the flow path  182  of the lower completion assembly  82 . In such case,  FIG. 5  illustrates the flow of high velocity fluid  54  as it travels from the jets  178  of debris removal tool  130 , through the openings or slots  120  of anchor assembly  114 , and into the interior of anchor assembly  114 . As shown, the flow of fluid  54  is directed into the annulus  214  between the snorkel  134  of debris removal tool  130  and the inner tubular surface  146  of anchor assembly  114 , thereby allowing flow to continue down suction tip  170  and circulate back into snorkel  134 , causing a low pressure condition within snorkel  134 . Debris  216  accumulated in lower completion assembly  82 , and in particular on or about the valve  180 , is sucked up by the fluid and low pressure condition of snorkel  134  through the opening  174 . 
     Although additional completion equipment  114  has been illustrated primarily as an anchor assembly  114 , or as an isolation tool assembly  114 , additional completion equipment  114  may be any component of or otherwise form part of either the lower completion assembly  82  or upper completion assembly  104  shown in  FIG. 1  so long as the additional completion equipment can be releasably attached to debris removal tool  130  for transport into a wellbore  12  as described herein. Thus, in this regard, additional completion equipment  114  need only include an engagement mechanism  166 , such as a shear mechanism, latch mechanism, or similar attachment mechanism, to permit the additional completion equipment  114  to be temporarily secured to the debris removal tool  130 . 
     With reference to  FIG. 6 , the operation  300  of the above described systems will be discussed. As generally described, the system is utilized in conjunction with a lower completion assembly  82  that has been deployed in a wellbore  12 . Thus, initially, a lower completion assembly  82  is deployed in a wellbore  12 . As part of the deployment, anchor mechanisms  192  of the lower completion assembly  82  may be set to secure the lower completion assembly  82  within the wellbore  12 . Likewise, sealing elements  190  may be actuated to seal the annulus  62  around the lower completion assembly  84 . Thus, in a first step  310 , a lower completion assembly  82  is deployed and secured within a wellbore  12 . The wellbore  12  may be cased or open hole. The completion assembly  82  may include one or more slips  192  and packers  190  that may be actuated to isolate screens adjacent various production zones. Thus, as part of the deployment, slips, such as slips  192 , may be set to secure various components of the lower completion assembly  82  within wellbore  12 , and packers may be actuated to seal the annulus  62  at various locations along the lower completion assembly  82 . 
     In step  312 , various lower completion activities may be performed. For example, gravel packing may performed. Likewise, flowback may be performed. In case of flowback, an isolation valve  180  may be closed and a closing sleeve  200  may be opened to permit fluid communication between a flowpath  182  within the lower completion assembly  84  and the wellbore annulus  62 . It will be appreciated that during these various activities, gravel, sands, shavings and other debris may collect within the lower completion assembly  82 , particularly adjacent the closed isolation valve  180 . 
     Once the various activities have been completed, in step  314 , a debris removal tool  130  is deployed in the wellbore  12 . The debris removal tool  130  includes additional completion equipment  114  removably attached to the debris removal tool  130 , and thus, the debris removal tool  130  is utilized to transport the additional completion equipment  114  into the wellbore  12 . The additional completion equipment  114  is secured to the debris removal tool  130  in such a way that the operation of the debris removal tool  130  is not inhibited, and thus, can be utilized to continue to conduct debris removal activities even with the additional completion equipment  114  attached. Thus, where the debris removal tool  130  includes a snorkel  134  or similar extension, the snorkel may extend beyond the second end  144  of the additional completion equipment  114 . In one or more embodiments, the debris removal tool  130  utilizes reverse circulation to vacuum debris and the additional completion equipment  114  is an anchor assembly  114 . In such case, the snorkel  134  of the debris removal tool  130  extends through the anchor assembly  114  and beyond the second end  144  of the anchor assembly  114 . In any event, the debris removal tool  130  is advanced to a location in the wellbore  12  that is in proximity to the lower completion assembly  82 , or otherwise to a point where it is desired to begin removal of debris. 
     In step  316 , the debris removal tool  130  is actuated, operated and utilized to remove accumulated gravel, sands, shavings and other debris as the debris removal tool  130  is moved into the vicinity of the lower completion assembly  82 . In embodiments utilizing reverse circulation for these wellbore cleaning operations, a pressurized working fluid  54  is pumped down to the debris removal tool  130  and released by jets  178  into the wellbore annulus  62  surrounding the debris removal tool  130 . The jetted fluid flow creates a low pressure condition within the debris removal tool  130  and high velocity flow along the exterior of the debris removal tool  130 , causing reverse circulation flow at the tip  170  of the debris removal tool  130 . 
     In step  318 , the anchor assembly  114  is stabbed into the lower completion assembly  82 . In embodiments of the system that include a latch mechanism  160  carried by the anchor assembly  114  and a corresponding latch sub  210  on the lower completion assembly  84 , the debris removal tool  130  is advanced until the latch mechanism  160  of the anchor assembly  114  engages the latch sub  210  of the lower completion assembly  82 , thereby locking or otherwise securing the anchor assembly  114  to the lower completion assembly  82 . In alternative embodiments, the anchor assembly  114  and the lower completion assembly  82  may include shoulders (not shown) that engage one another for relative positioning of the anchor assembly  114 . In any event, it will be appreciated that in the foregoing embodiments, the length L 1  of the of the snorkel  134  may be selected so that when the anchor assembly  114  is secured or engaged by the lower completion assembly  82 , the snorkel tip  170  is spaced apart a desired distance from the isolation valve  180 , thereby mitigating against damage to the isolation valve  180  by the snorkel  134 . In embodiments of the system where a latch mechanism  160  and latch sub  210  (or shoulders) are not present, then the anchor assembly  114  may simply be stabbed into the lower completion assembly  82  and allowed to “float” relative to the lower completion assembly  82 . In either case, external seals  152 ,  162  carried on the anchor assembly  114  seal against the adjacent walls surfaces  194 ,  208  of the lower completion assembly  82 . 
     It will be appreciated that because of seals  152 ,  162  between the lower completion assembly  82  and the anchor assembly  114 , the reverse circulation flow of the debris removal tool  130  would be inhibited once anchor assembly  114  is engaged with lower completion assembly  82 . However, the presence of perforations or slots  120  permit the reverse circulation flow of debris removal tool  130  to continue. Thus, in step  320 , the high velocity flow emanating from the debris removal tool  130  is ported or otherwise directed by perforations  120  into the interior of the anchor assembly  114  and along the annulus  214  between the anchor assembly  114  and the snorkel  134  of the debris removal tool  130 . Because of the low pressure condition within the debris removal tool  130 , debris adjacent the distal end of the snorkel  134  is drawn or sucked into the snorkel  134  for removal. 
     In step  322 , the debris removal tool  130  is disengaged from the anchor assembly  114 . In one or more embodiments, an axial or rotational force is applied to the debris removal tool  130 , causing the mechanism  166  securing the anchor assembly  114  to the debris removal tool  130  to shear, thereby separating the debris removal tool  130  from the anchor assembly  114 . In other embodiments, axial and/or rotational forces may be applied to the debris removal tool  130  to cause an engagement mechanism  166  securing the debris removal tool  130  and to the anchor assembly  114  to disengage. 
     Once the debris removal tool  130  has been separated from the anchor assembly  114 , the debris removal tool  130  may continue to be utilized to remove debris. For example, the debris removal tool  130  may be advanced farther into the wellbore  12  so that the suction tip  170  of the snorkel  134  is adjacent the valve  180 . In this regard, the debris removal tool  130  may be used to toggle valve  80  in order to better remove debris from around valve  80 . 
     Finally, it step  324 , the debris removal tool is retrieved from the wellbore, leaving the anchor assembly engaged with the lower completion assembly  82  and in place for engagement with an upper completion assembly  104  or other wellbore equipment. 
     Thus, isolation seal assembly for use in a wellbore has been described. Embodiments of the isolation seal assembly may generally include a tubular with a first end and a second end and an outer tubular surface; a first latch mechanism disposed on tubular adjacent first end; a first seal assembly positioned along outer tubular surface between first latch mechanism and second end of tubular; and one or more openings formed along tubular between first latch mechanism and the first seal assembly. Similarly, a system for placement of an engagement mechanism in a wellbore has been described. Embodiments of the placement system may generally include a debris removal tool; and an isolation seal assembly releasably attached to the debris removal tool, the isolation seal assembly comprising a tubular having a through bore extending between a first end and a second end, the tubular also having an outer tubular surface; a first latch mechanism disposed on tubular adjacent first end; a first seal assembly positioned along outer tubular surface between first latch mechanism and second end of tubular; and one or more openings formed along tubular between first latch mechanism and the first seal assembly. Other embodiments of the placement system may generally include a debris removal tool; and completion equipment releasably attached to the debris removal tool. 
     For any of the foregoing embodiments, the apparatus may include any one of the following elements, alone or in combination with each other:
         A second latch mechanism positioned along tubular between openings and the second end.   A second seal assembly positioned along outer tubular surface between first seal assembly and the second end of the tubular.   The tubular includes an elongated portion between the first and second seal assemblies with the second seal assembly positioned adjacent the second end of tubular.   A releasable engagement mechanism adjacent the first end of the tubular.   The engagement mechanism comprises a shear element selected from the group consisting of a shear ring, a shear bolt and a shear pin.   The first latch mechanism is a releasable engagement mechanism adjacent the first end of the tubular.   A seal positioned along an inner surface of the tubular adjacent the engagement mechanism.   A seal assembly comprises an elastomeric element seated in a recess formed in surface of the tubular.   The openings extend from an inner surface of the tubular to the outer surface of the tubular.   The debris removal tool comprises a sub having jet nozzles and a head from which an elongated snorkel extends, wherein the snorkel extends beyond the second end of the anchor assembly.   The snorkel has a snorkel length and the anchor assembly has an anchor assembly length that is shorter than the snorkel length.   A lower completion assembly having a packer assembly positioned at a first end of the lower completion assembly, a sand control screen spaced apart from the packer assembly; and an isolation valve disposed along a flow path defined in the lower completion assembly between the sand control screen and the packer assembly, wherein the isolation seal assembly is engaged with the lower completion assembly so that the through bore of the isolation seal assembly is in fluid communication with the flow path of the lower completion assembly.   The isolation seal assembly further comprises a second latch mechanism positioned along the tubular between the openings and the second end of the tubular; and the lower completion assembly comprises a latch sub positioned adjacent the packer assembly, wherein the second latch mechanism of the isolation seal assembly engages the latch sub of the lower completion assembly.   The lower completion assembly further comprises a closing sleeve disposed between the isolation valve and the packer assembly, wherein the closing sleeve has an elongated tubular with at least one port provided therein.   The isolation seal assembly further comprises a second seal assembly positioned along outer tubular surface between first seal assembly and the second end of the tubular, and wherein the isolation seal assembly engages the lower completion assembly so that the at least one port of the closing sleeve is positioned between the first and second seal assemblies, blocking the port from fluid communication with the flow path of the lower completion assembly.   A second latch mechanism positioned along tubular between openings and the second end; a releasable engagement mechanism adjacent the first end of the tubular, the engagement mechanism comprises a shear element selected from the group consisting of a shear ring, a shear bolt and a shear pin.   At least a portion of a lower completion assembly installed in a wellbore and spaced apart from the debris removal tool and completion equipment attached thereto, wherein the wherein the debris removal tool comprises a head and the completion equipment comprises a first end and a second end and an engagement mechanism adjacent the first end, the engagement mechanism securing the completion equipment to the head of the debris removal tool.   The debris removal tool further comprises an elongated snorkel extending from the head, wherein the snorkel extends beyond the second end of the completion equipment.   The snorkel has a snorkel length and the completion equipment has a completion equipment length that is shorter than the snorkel length.       

     Thus, a method for deploying completion equipment in a wellbore has been described. Embodiments of the deployment method include releasably attaching completion equipment to a reverse circulation debris removal tool; advancing the debris removal tool into a wellbore to a location in proximity to a lower completion assembly; initiating operation of the debris removal tool utilizing reverse circulation; engaging the completion equipment with the lower completion assembly; and continuing to operate the debris removal tool by porting reverse circulation flow into the interior of the completion equipment. 
     For the foregoing embodiments, the method may include any one of the following steps, alone or in combination with each other:
         Applying a shearing force to the reverse circulation debris removal tool to separate the debris removal tool from the completion equipment; and withdrawing the debris removal tool from the wellbore while leaving the completion equipment engaged with the lower completion assembly.   Engaging comprises manipulating the debris removal tool so that a latch mechanism on the completion equipment attaches to a latch on the lower completion assembly so as to lock the completion equipment to the lower completion assembly.   Positioning the debris removal tool relative to the lower completion assembly so that flow through a closing sleeve is blocked.   Utilizing the debris removal tool to toggle an isolation valve once the debris removal tool has been separated from the completion equipment.   Utilizing the debris removal tool to toggle an isolation valve.       

     Although various embodiments have been shown and described, the disclosure is not limited to such embodiments and will be understood to include all modifications and variations as would be apparent to one skilled in the art. Therefore, it should be understood that the disclosure is not intended to be limited to the particular forms disclosed; rather, the intention is to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the disclosure as defined by the appended claims.