Patent Publication Number: US-11041357-B2

Title: Annular bypass packer

Description:
BACKGROUND 
     The present disclosure relates to oil and gas exploration and production, and more particularly to a production system for use in extracting hydrocarbons from a geological formation. 
     During the operation of a well, it may be desirable to isolate portions of the well from one another such that certain segments, or zones, of the well are not in direct fluid equilibrium with one other. To provide such isolations, one or more packers may be placed along segments of a workstring to form a relative seal across the annulus formed by the external surface of the workstring and the wall of the wellbore. 
     SUMMARY 
     The present disclosure relates to oil and gas exploration and production, and more particularly to a production system for use in extracting hydrocarbons from a geological formation. 
     In accordance with a first illustrative embodiment, a packer includes a first conduit extending from a first end of the packer to a second end of the packer, and a second conduit adjacent to the first conduit. A portion of the second conduit is formed by an outer surface of the first conduit. The packer further includes a swelling element surrounding the first conduit and second conduit. The first end of the packer includes a bulkhead manifold having a transition section forming a fluid coupling from at least one external bypass conduit to the second conduit. The swelling element is operable to form a seal against a wellbore wall upon exposure to a swell fluid. 
     In accordance with a second illustrative embodiment, a system for facilitating fluid flow to a wellbore includes a fluid supply source that is fluidly coupled to an annulus of a wellbore and a packer. The packer has a first conduit extending from a first end of the packer to a second end of the packer and a second conduit adjacent to the first conduit. A portion of the second conduit is formed by an outer surface of the first conduit. The packer also includes a swelling element that surrounds and radially encloses the first conduit and second conduit. The first end of the packer includes a bulkhead manifold having a transition section that forms a fluid coupling from at least one external bypass conduit to the second conduit, and the swelling element is operable to form a seal against a wellbore wall upon exposure to a swell fluid. The first end of the packer is fluidly coupled to the fluid supply source via an external bypass conduit, and the second conduit is fluidly coupled to the annulus of the wellbore at the second end of the annulus bypass packer. 
     In accordance with another illustrative embodiment, a method of providing fluid flow to a wellbore includes supplying a fluid to an annulus of a wellbore from a fluid supply source. The method also includes supplying fluid to a first end of a packer. The packer has a first conduit extending from the first end of the packer to a second end of the packer and a second conduit adjacent to the first conduit. A portion of the second conduit is formed by an outer surface of the first conduit. The packer also includes a swelling element surrounding the first conduit and second conduit. The first end of the packer includes a bulkhead manifold having a transition section forming a fluid coupling from at least one external bypass conduit to the second conduit. The swelling element of the packer is operable to form a seal against a wellbore wall upon exposure to a swell fluid. The first end of the packer is fluidly coupled to the fluid supply source via an external bypass conduit, and the second end of the packer is fluidly coupled to an injection zone of the wellbore. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       The following figures are included to illustrate certain aspects of the present disclosure, and should not be viewed as exclusive embodiments. The subject matter disclosed is capable of considerable modifications, alterations, combinations, and equivalents in form and function, without departing from the scope of this disclosure. 
         FIG. 1  illustrates a schematic view of an on-shore well having a production system according to an illustrative embodiment; 
         FIG. 2  illustrates a schematic view of an off-shore well having a production system according to an illustrative embodiment; 
         FIG. 3  is a detail view of a portion of the production system of  FIG. 1 ; 
         FIG. 4  is a detail view of a single-manifold annular bypass packer deployed in the production system shown in  FIGS. 1-3 ; 
         FIG. 4A  is a section view, showing a portion of the annular bypass packer of  FIG. 4 , taken along the lines  4 A- 4 A; 
         FIG. 4B  is a section view, showing a portion of the annular bypass packer of  FIG. 4 , taken along the lines  4 B- 4 B; 
         FIG. 4C  is a section view, showing a portion of the annular bypass packer of  FIG. 4 , taken along the lines  4 C- 4 C; 
         FIG. 4D  is a section view, showing a portion of the annular bypass packer of  FIG. 4 , taken along the lines  4 D- 4 D; 
         FIG. 5  is a detail view of a dual-manifold annular bypass packer deployed in the production system shown in  FIGS. 1-3 ; 
         FIG. 6  is a side, cross-section view of an alternative embodiment of a single-manifold annular bypass packer; 
         FIG. 6A  is a section view, showing a portion of the annular bypass packer of  FIG. 6 , taken along the lines  6 A- 6 A; 
         FIG. 6B  is a section view, showing a portion of the annular bypass packer of  FIG. 6 , taken along the lines  6 B- 6 B; 
         FIG. 6C  is a section view, showing a portion of the annular bypass packer of  FIG. 6 , taken along the lines  6 C- 6 C; 
         FIG. 6D  is a section view, showing a portion of the annular bypass packer of  FIG. 6 , taken along the lines  6 D- 6 D; 
     
    
    
     DETAILED DESCRIPTION OF ILLUSTRATIVE EMBODIMENTS 
     In the following detailed description of the illustrative embodiments, reference is made to the accompanying drawings that form a part hereof. These embodiments are described in sufficient detail to enable those skilled in the art to practice the invention, and it is understood that other embodiments may be utilized and that logical structural, mechanical, electrical, and chemical changes may be made without departing from the spirit or scope of the invention. To avoid detail not necessary to enable those skilled in the art to practice the embodiments described herein, the description may omit certain information known to those skilled in the art. The following detailed description is, therefore, not to be taken in a limiting sense, and the scope of the illustrative embodiments is defined only by the appended claims. 
     The present disclosure relates to a packer having an annular bypass feature that provides for the passage of a fluid pathway from one zone of a wellbore to the next to selectively provide for delivering a pressurized fluid to the zone or isolating the zone from the pressurized fluid. 
     Unless otherwise specified, any use of any form of the terms “connect,” “engage,” “couple,” “attach,” or any other term describing an interaction between elements is not meant to limit the interaction to direct interaction between the elements and may also include indirect interaction between the elements described. In the following discussion and in the claims, the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to.” Unless otherwise indicated, as used throughout this document, “or” does not require mutual exclusivity. 
     As used herein, the phrases “hydraulically coupled,” “hydraulically connected,” “in hydraulic communication,” “fluidly coupled,” “fluidly connected,” and “in fluid communication” refer to a form of coupling, connection, or communication related to fluids, and the corresponding flows or pressures associated with these fluids. In some embodiments, a hydraulic coupling, connection, or communication between two components describes components that are associated in such a way that fluid pressure may be transmitted between or among the components. Reference to a fluid coupling, connection, or communication between two components describes components that are associated in such a way that a fluid can flow between or among the components. Hydraulically coupled, connected, or communicating components may include certain arrangements where fluid does not flow between the components, but fluid pressure may nonetheless be transmitted such as via a diaphragm or piston or other means of converting applied flow or pressure to mechanical or fluid force. 
     While a portion of a wellbore may in some instances be formed in a substantially vertical orientation, or relatively perpendicular to a surface of the well, the wellbore may in some instances be formed in a substantially horizontal orientation, or relatively parallel to the surface of the well, the wellbore may include portions that are partially vertical (or angled relative to substantially vertical) or partially horizontal (or angled relative to substantially horizontal). In some wellbores, a portion of the wellbore may extend in a downward direction away from the surface and then back up toward the surface in an “uphill,” such as in a fish hook well. The orientation of the wellbore may be at any angle leading to and through the reservoir. 
     Referring now to the figures,  FIG. 1  illustrates a schematic view of a well  100  operating a production system  102  according to an illustrative embodiment. The well  100  includes a wellbore  104  that extends from the surface  106  of the well  100  to a subterranean substrate or formation  108 . The well  100  and production system  102  are illustrated onshore in  FIG. 1 . Alternatively,  FIG. 2  illustrates a schematic view of an offshore platform  150  operating the production system  102  according to an illustrative embodiment. The production system  102  in  FIG. 2  may be deployed in a sub-sea well  152 , shown in  FIG. 2 , accessed by the offshore platform  150 , shown in  FIG. 2 . The offshore platform  150  may be a floating platform or may instead be anchored to a seabed  154 , shown in  FIG. 2 . It is noted that while the illustrated embodiments of  FIGS. 1 and 2  contemplate a system in which injection fluid may be delivered to a wellbore via the workstring  110  or annulus  116  (as described in more detail below), in other embodiments it may be preferable to delivery injection fluid via a second tube run into the annulus  116 . 
     In the embodiments illustrated in  FIGS. 1 and 2 , the wellbore  104  has been formed by a drilling process in which dirt, rock and other subterranean material is removed to create the wellbore  104 . During or after the drilling process, a portion of the wellbore may be cased with a casing (not illustrated). In other embodiments, the wellbore may be maintained in an open-hole configuration without casing. The embodiments described herein are applicable to either cased or open-hole configurations of the wellbore  104 , or a combination of cased and open-hole configurations in a particular wellbore. 
     After drilling of the wellbore is complete and the associated drill bit and drill string are “tripped” from the wellbore  104 , a workstring  110 , shown as a production string, is lowered into the wellbore  104 . The workstring  110  may include sections of tubing, each of which are joined to adjacent tubing by threaded or other connection types. The work string may refer to the collection of pipes or tubes as a single component, or alternatively to the individual pipes or tubes that comprise the string. The term work string (or tubing string or production string) is not meant to be limiting in nature and may refer to any component or components that are capable of being coupled to the production system  102  to lower or raise the production system  102  in the wellbore  104  or to provide energy to the production system  102  such as that provided by fluids, electrical power or signals, or mechanical motion. Mechanical motion may involve rotationally or axially manipulating portions of the workstring  110 . In some embodiments, the workstring  110  may include a passage disposed longitudinally in the workstring  110  that is capable of allowing fluid communication between the surface  106  of the well  100  and a downhole location. 
     The production system  102  may include a fluid collection system  112  for receiving fluid extracted from the formation  108  via the workstring  110 . The production system  102  may also include a fluid delivery system  114  having a fluid supply source that may be used to, for example, apply a pressurized fluid to at least a portion of an annulus  116  formed between the external surface of the workstring  110  and the internal wall of the wellbore  104 . As described in more detail below, in some production environments, it may be desirable to apply a pressurized fluid to a segment, or zone of the well  100  while simultaneously extracting fluid from another zone of the well  100 . To that end, the production system  102  may include a controller  118  that is controlled by remote or local operator or control system to control the functions of the production system  102  (e.g., to facilitate the production of fluid from the workstring  110  or the application of fluid to the annulus  116 ). 
       FIG. 3  shows a detail view of a portion of the workstring  110  that spans multiple zones of the formation  108  and, more particularly, a subsystem  300  for selectively applying a pressurized fluid to the annulus  116 . For illustrative purposes, the formation  108  is shown as including alternating injection zones  302 , in which a pressurized fluid is applied to the formation  108  via the annulus  116 , and production zones  304  in which wellbore fluids are harvested from the formation  108  by allowing fluid to pass from the formation  108  across the annulus  116  and through a screen or perforations in the workstring  110 , or through a manually or remotely operated sleeve that selectively allows production fluid into the workstring  110 . In the injection zones  302 , the workstring  110  includes a first tubing interval  314  that facilitates the injection of fluids to the formation  108 . Correspondingly, in the production zones  304 , the workstring  110  includes a second tubing interval  310  that facilitates collection of fluid from the formation  108 . To fluidly isolate the portions of the annulus  116  that adjoin each injection zone  302  from those that adjoin each production zone  304 , a packer  312  is positioned between each zone to form a seal between the internal wall of the wellbore  104  and the external surface of the workstring  110 . In the case of an isolation zone, the injection fluid may be restricted from flowing into the zone and wellbore fluid may be restricted from flowing into the workstring. In the case of an injection zone  302 , injection fluid may be supplied to the injection zone  302  via the annulus  116 . Alternatively, injection fluid may be supplied via a bypass opening in the workstring  110 , which could be automatically or manually controlled. In the case of a controlled opening, control may be facilitated via optional control lines. Such control lines could be independently routed through the packer, or routed through the bulkhead connection and bypass conduit, as described in more detail below. 
     Each such packer  312  may be a swell packer that comprises an elastomer or similar expandable material that is selected or configured to expand upon being exposed to a target fluid, which may be a fluid from the formation  108  or a fluid delivered to the wellbore by an operator. 
     In an illustrative embodiment, the packer  312  may be a single manifold, annular bypass packer that includes a manifold interface at a first end, and facilitates the passage of fluid across a sealing element of the packer  312  from an uphole portion of the annulus to a downhole portion of the annulus (or vice versa). In another illustrative embodiment, the packer  312  may be a dual-manifold packer that includes a manifold interface at each end of the packer  312 , and also facilitates an annular bypass of the sealing element of the packer  312 . As referenced herein with respect to elements in a wellbore, “uphole from” means closer to the surface of the well, taken along the path of the wellbore, and “downhole from” means further away from the surface of the well, taken along the path of the wellbore. 
     An example of a single manifold embodiment is described in more detail with regard to  FIG. 4  and cross-sections  4 A- 4 D. Here, the annular bypass packer  412  is shown as isolating a production zone at a first end  420  from an injection zone at a second end  422  of the annular bypass packer  412 . The annular bypass packer  412  includes a central conduit  424 , which may be referred to as a first conduit that is fluidly coupled to a primary flow path of the workstring  110 . The central conduit  424  may be formed from a tubing segment and extends from the first end  420  of the packer to the second end  422  of the packer  412  to convey fluid through the workstring  110 . The packer  412  also includes a second conduit  426  that is operable to convey fluid along the annulus  116 , outside of the primary flow path (and associated central conduit  424 ). The second conduit  426  may be formed by enclosing an area that borders the central conduit  424  thereby using an outer boundary of the central conduit  424  to form the second conduit  426 . More particularly, the second conduit  426  may be formed by cutting a second tubing segment and joining the cut tubing to an external surface of tubing that forms the primary conduit  424 . In some embodiments, the cut tubing may be tubing that has a similar diameter to tubing of the central conduit  424  in half, and seam-welding the half tube to the exterior of the tubing of the central conduit  424 . 
     Both the central conduit  424  and second conduit  426  are enclosed, or radially surrounded, by sealing element  430 , which may be formed from, for example, an elastomeric material that swells in the presence of a fluid to form a compressive seal between the external surface of the central conduit  424  and secondary conduit  426  at the interior, and the wall of the wellbore  104  at the exterior. The sealing element  430  may be bounded at each end by end rings  436  that restrict longitudinal expansion of the sealing element  430  as it expands. The end rings  436  may have a cross-section that complements that of the central conduit  424  and second conduit  426 , and therefore may have an inner surface that is oval, or resembling two partial-circular portions joined together, with each partial-circular section having a center-point that is offset from the center-point of the other partial-circular section. The end rings  436  may have an external surface that is circular to correspond to the internal wall of the wellbore  104 . The sealing element  430  may include one or more (optional) control line passages  428 , to facilitate the passages of relatively small diameter control lines that do not effect material additional stresses on the sealing element  430  as it expands. 
     To facilitate fluid flow across zones, the annular bypass packer  412  may include a bulkhead manifold  414 . An exemplary bulkhead manifold  414  is described with regard to  FIG. 4A , and is shown as having one or more fluid coupling conduits  432  that are operable to couple to one or more external bypass conduits  416  or other couplings that are external to the packer  412 , as shown in  FIG. 4 . The bulkhead manifold  414  may be formed by machining, casting, or any other suitable fabrication technique, and provides a fluid communication port from the fluid coupling conduits  432  to the second conduit  426 . As such, the fluid coupling conduits  432  may feed into, or otherwise transition to, the second conduit  426  to allow fluid flow from the external bypass conduits  416  to the second conduit  426  through the bulkhead manifold  414 . The bulkhead manifold  414  may be joined to the first end  420  of the packer  412  by welding or any other suitable joining technique. As shown in  FIG. 4A , the bulkhead manifold  414  includes fluid coupling conduits  432  at a first end and a portion of the central conduit  424  at a second end. Through the body of the bulkhead manifold  414 , the fluid coupling conduits  432  converge to feed into the second conduit  426  when the bulkhead manifold  414  is joined to the annulus bypass packer  412 . In some embodiments, the fluid coupling conduits may converge to a bypass conduit  425  (within the body of the bulkhead manifold  414 ) having a profile that mates to the second conduit  426  of the annulus bypass packer  412  when the bulkhead manifold  414  is joined to the annulus bypass packer  412  (see, e.g., transition section  FIG. 4B ). 
     The external bypass conduits  416  may be used to, for example, convey a fluid from fluid delivery system  114  or from an uphole portion of the annulus  116  across a zone in isolation from other fluid in the annulus  116 , thereby isolating a portion of the formation that abuts the relevant zone from the fluid in the external bypass conduits  416 . As such, the external bypass conduits  416  may form a portion of the workstring  110  that passes through a production zone  304  (i.e., a second tubing interval  310 ) by allowing fluid to pass through the external bypass conduits  416  across the production zone without interfering or intermixing with wellbore fluid in the zone, which may be passing from the formation to the primary conduit of the workstring  110  (e.g., through a screen) for collection and production. 
     In some embodiments, the second end  422  of the annular bypass packer  412  is configured to deliver fluid from the second conduit  426  to the annulus  116 , as shown in  FIG. 4D . In such an embodiment, the second conduit  426  may terminate prior to where the central conduit  424  is joined to an adjacent segment of the work string  110 . This configuration may be used to, for example, provide fluid communication from a fluid delivery system  114  to the annulus  116  (e.g. at first tubing interval  314 ) to, for example, pressurize the formation  108  in an injection zone  302 . 
     The packer configuration described above provides an advantage to the annular bypass packer as compared to a traditional swell packer by removing the need for bypass flow tubes (analogous to external bypass conduits  416 ) to traverse the sealing element of the packer. Such bypass flow tubes may be significantly larger diameter than traditional, relatively small diameter control lines such as 0.25″ diameter control lines that are typically used to traverse swell packer sealing elements, as large diameter tubes facilitate a high fluid flow rate that may be necessary to affect reservoir performance. The 0.25″, smaller diameter tubes (control lines) are used to house an electrical or glass fiber conductor, or to supply hydraulic fluid to actuate a downhole tool. To provide a traditional packer with the ability to couple to external bypass conduits  416 , such traditional swell packers would need to incorporate a relatively large void along the entire length of the packer sealing element, into which a fluid supply conduit (i.e., a flow tube) could be inserted prior to running the packer into the well. Such voids and flow tubes could generate magnified local stress points, ultimately decreasing the reliability or sealing ability of the packer and increasing the amount of rig time needed to install the packer. In the configurations described with regard to  FIGS. 4-5 , the need for such voids is eliminated in favor of the disclosed annular bypass and manifold system. 
     Another embodiment of an annular bypass packer  512  is described with regard to  FIG. 5 , which depicts a dual-manifold packer  512 . In  FIG. 5 , the annular bypass packer  512  is shown as isolating a production zone  304  from a second production zone  304 . The annular bypass packer  512  is otherwise analogous in many respects to the annular bypass packer  412  of  FIG. 4 . The annular bypass packer  512  includes a central conduit  524 , which may be referred to as a first conduit, and is fluidly coupled to a primary flow path of the workstring  110 . The central conduit  524  extends from a first end  520  of the annular bypass packer to a second end  522  of the annular bypass packer  512  to convey fluid through the workstring  110 . The annular bypass packer  512  also includes a second conduit  526  that is operable to convey fluid along the annulus  116 , outside of the primary flow path of the central conduit  524 . 
     Both the central conduit  524  and second conduit  526  are radially surrounded and enclosed by sealing element  530 , which (when activated) may form a compressive seal between the external surface of the central conduit  520  and second conduit  526  at the interior, and the wall of the wellbore  104  at the exterior. The sealing element  530  may include one or more optional control line passages (analogous to line passages  428  of  FIG. 4C ), to facilitate the passage of relatively small diameter control lines. 
     To facilitate fluid flow across zones, the annular bypass packer  512  may include a first bulkhead manifold  514  at the first end  520  and a second bulkhead manifold  515  at the second end  522 . The first bulkhead manifold may be identical to the bulkhead manifold  414  described above with regard to  FIGS. 4 and 4A-4B , and the second bulkhead manifold  515  may be similarly fabricated but oriented at the second end  522  of the annular bypass packer  512  opposite the first bulkhead manifold  514 . Each bulkhead manifold may have one or more fluid coupling conduits (analogous to fluid coupling conduits  432  of  FIG. 4A ) that are operable to couple to one or more external bypass conduits  516  or other couplings that are external to the annular bypass packer  512 , as shown in  FIG. 5 . The first bulkhead manifold  514  and second bulkhead manifold  515  may be formed by machining, casting, or any other suitable fabrication technique, and each provides a fluid communication port from the fluid coupling conduits  532  to the second conduit  526 . As such, the fluid coupling conduits  532  may feed into, or otherwise transition to, the second conduit  526  to allow fluid flow from the external bypass conduits  516  (which may be uphole external bypass conduits) to the second conduit  526  from the first bulkhead manifold  514  to the second bulkhead manifold  515  and, in turn, second external bypass conduits  516  (which may be downhole external bypass conduits). Such an arrangement may facilitate flow from, for example, a first production zone to a second production zone. 
     Another embodiment of a single manifold bypass packer is shown in  FIG. 6  and cross-sections  6 A- 6 D. The annular bypass packer  612  is again shown as isolating a production zone at a first end  620  from an injection zone at a second end  622  of the annular bypass packer  612 . The annular bypass packer  612  includes a central conduit  624 , which may be referred to as a first conduit that is fluidly coupled to a primary flow path of the workstring  110 . The central conduit  624  extends from the first end  620  of the packer to the second end  622  of the packer  612  to convey fluid through the workstring  110 . The packer  612  also includes a second conduit  626  that is operable to convey fluid along the annulus  116 , outside of the primary flow path (and associated central conduit  624 ). The second conduit  626  may be formed by enclosing an area that borders the central conduit  624  thereby using an outer boundary of the central conduit  624  to form the second conduit  626 . More particularly, the second conduit  626  may be formed by cutting a piece of tubing and joining the cut tubing to an external surface of tubing that forms the primary conduit  624 . In some embodiments, the cut tubing may be tubing that has a similar diameter to tubing of the central conduit  624  in half, and seam-welding the half tube to the exterior of the tubing of the central conduit  624 . 
     Both the central conduit  624  and second conduit  626  are enclosed, or radially surrounded, by sealing element  630 , which may be formed from, for example, an elastomeric material that swells in the presence of a fluid to form a compressive seal between the external surface of the central conduit  624  and secondary conduit  626  at the interior, and the wall of the wellbore  104  at the exterior. The sealing element  630  may be bounded at each end by end rings  636  that restrict longitudinal expansion of the sealing element  630  as it expands. The end rings  636  may have a cross-section that complements that of the central conduit  624  and second conduit  626 , and be therefore be oval, or may have two partial-circular portions joined together, with each partial-circular section having a center-point that is offset from the center-point of the other partial-circular section. 
     To facilitate fluid flow across zones, the annular bypass packer  612  may include a bulkhead manifold  614 . An exemplary bulkhead manifold  614  is described with regard to  FIG. 6A , and is shown as having one or more fluid coupling conduits  632  that are operable to couple to one or more external bypass conduits  616 , control line conduits  628 , or other couplings that are external to the packer  612 , as shown in  FIG. 6 . The bulkhead manifold  614  may be formed by machining, casting, or any other suitable fabrication technique, and provides a fluid communication port from the fluid coupling conduits  632  to the second conduit  626 . As such, the fluid coupling conduits  632  may feed into, or otherwise transition to, the second conduit  626  to allow fluid flow from the external bypass conduits  616  to the second conduit  626  through the bulkhead manifold  614 . Similarly, in this embodiment, the control line conduits  628  may be routed through the second conduit  626 , thereby alleviating the need for any other passages through the swell element of the packer  612 . 
     The bulkhead manifold  614  may be joined to the first end  620  of the packer  612  by welding or any other suitable joining technique. As shown in  FIG. 6A , the bulkhead manifold  614  includes fluid coupling conduits  632  at a first end and a portion of the central conduit  624  at a second end. Through the body of the bulkhead manifold  614 , the fluid coupling conduits  632  converge to feed into the second conduit  626  when the bulkhead manifold  614  is joined to the annulus bypass packer  612 . In some embodiments, the fluid coupling conduits may converge to a bypass conduit  625  (within the body of the bulkhead manifold  614 ) having a profile that mates to the second conduit  626  of the annulus bypass packer  612  when the bulkhead manifold  614  is joined to the annulus bypass packer  612  (see, e.g., transition section  FIG. 6B ). 
     In some embodiments, the second end  622  of the annular bypass packer  612  is configured to deliver fluid from the second conduit  626  to the annulus  116 , as shown in  FIG. 6D . In such an embodiment, the second conduit  626  may terminate prior to where the central conduit  624  is joined to an adjacent segment of the work string  110 . This configuration may be used to, for example, provide fluid communication from a fluid delivery system  114  to the annulus  116  (e.g. at first tubing interval  314 ) to, for example, pressurize a formation in an injection zone. 
     In operation, the above-described system may be deployed and operated to simultaneously pressurize and produce from a formation  108 . In accordance with an illustrative method, a workstring is deployed to a wellbore in a manner such that packers, such as packers  412  or  512  described above, isolate the various zones of the wellbore  104 , including production zones  304  and injection zones  302 , as described with regard to  FIG. 3 , and isolation zones (not shown). As referenced herein, isolation zones are segments of the wellbore that are fluidly isolated from the production zones  304  and injection zones  302 . The fluid supply source  114  may be operated to supply a pressurized fluid to the annulus  116  of the wellbore  104  at injection zones  302 . 
     To facilitate the application of the pressurized fluid, an injection fluid may be supplied via the annulus  116  to external bypass conduits (such as external bypass conduits  416  and  516 ) that traverse the production zones  304 . The injection fluid may be conveyed from the production zones  304  to the injection zones  302  using the annular bypass packers  412  described above, which may be alternatingly positioned and oriented to transfer the injection fluid from the annulus  116  to the fluid supply lines  416  that traverse the production zones  304  and back at the injection zones  302 , the injection fluid is in equilibrium with the annulus of the wellbore, thereby injecting fluid to the formation. Simultaneously, hydrocarbon-bearing fluid may be extracted from the formation  108  at the production zones  304 , where the workstring may be screened or otherwise opened to allow the passage of fluid from the formation to the central conduit of the workstring  110  via the annulus  116 . 
     A reverse embodiment is also contemplated, in which the flow directions described above may be reversed, such that an injection fluid may be supplied via the central conduit of the workstring  110  through screened or similar vented segments that traverse the injection zones. Correspondingly, production fluid may be harvested via external bypass conduits (such as external bypass conduits  416  and  516 ) that traverse the annulus  116  within injection (or isolation) zones. In such an embodiment, production fluid may be conveyed from the production zones toward the surface for collection using the annular bypass packers  412  described above, which may be alternatingly positioned and oriented to transfer the production fluid from the annulus  116  to fluid supply lines  416  that traverse injection zones. 
     It should be apparent from the foregoing that embodiments of an invention having significant advantages have been provided. While the embodiments are shown in only a few forms, the embodiments are not limited but are susceptible to various changes and modifications without departing from the spirit thereof. As such, the present disclosure should be understood to cover at least the following examples: 
     Example 1 
     A packer comprising: a first conduit extending from a first end of the packer to a second end of the packer; a second conduit adjacent to the first conduit, wherein a portion of the second conduit is formed by an outer surface of the first conduit; and a swelling element surrounding the first conduit and second conduit. The first end of the packer comprises a bulkhead manifold having a transition section forming a fluid coupling from at least one external conduit to the second conduit, and the swelling element is operable to form a seal against a wellbore wall upon exposure to a fluid. 
     Example 2 
     The packer of example 1, wherein the bulkhead manifold comprises a transition portion fluidly coupling the second conduit to an external bypass conduit. 
     Example 3 
     The packer of example 1, wherein the external bypass conduit comprises a small-diameter control line. 
     Example 4 
     The packer of example 1, wherein the bulkhead manifold is a first bulkhead manifold, and wherein the second end of the packer comprises a second bulkhead manifold. 
     Example 5 
     The packer of example 1, further comprising an end ring coupled to the swelling element of the packer and operable to limit the longitudinal expansion of the swelling element, wherein the swelling element has an internal profile that complements the external profile of the first conduit and the second conduit. 
     Example 6 
     The packer of example 1, wherein the first conduit comprises a first tubing segment, and wherein the second conduit comprises a portion of a second tubing segment that is joined to the first tubing segment. 
     Example 7 
     The annular bypass packer of example 6, wherein the second tubing segment is seam-welded to the first tubing segment. 
     Example 8 
     A system for providing fluid flow to a wellbore, the system comprising: a fluid supply source fluidly coupled to an annulus of a wellbore; and a packer. The packer has (1) a first conduit extending from a first end of the packer to a second end of the packer; (2) a second conduit adjacent to the first conduit, wherein a portion of the second conduit is formed by an outer surface of the first conduit; and (3) a swelling element surrounding the first conduit and second conduit, wherein the first end of the packer comprises a bulkhead manifold having a transition section forming a fluid coupling from at least one external conduit to the second conduit, and wherein the swelling element is operable to form a seal against a wellbore wall upon exposure to a wellbore fluid. The first end of the packer is fluidly coupled to the fluid supply source via an external bypass conduit. 
     Example 9 
     The system of example 8, wherein the second conduit is fluidly coupled to the annulus of the wellbore at the second end of the packer. 
     Example 10 
     The system of example 8, wherein the bulkhead manifold comprises a transition portion fluidly coupling the second conduit to an external bypass conduit. 
     Example 11 
     The system of example 8, wherein the first conduit comprises a first tubing segment, and wherein the second conduit is formed by an outer surface of the first tubing segment and an internal portion of a second tubing segment that is joined to the first tubing segment. 
     Example 12 
     The system of example 11, wherein the second tubing segment is seam-welded to the first tubing segment. 
     Example 13 
     The system of example 8, wherein the packer comprises a plurality of first packers, and further comprising a plurality of second packers. 
     Example 14 
     The system of example 13, wherein the bulkhead manifold of each of the first plurality of annular bypass packers is fluidly coupled to an external bypass conduit extending through a production zone. 
     Example 15 
     The system of example 13, wherein the second end of each of the first plurality of annular bypass packers is fluidly coupled to the annulus of the wellbore at an injection zone. 
     Example 16 
     The system of example 13, wherein the bulkhead manifold of each of the plurality of second packers is fluidly coupled to an external bypass conduit extending through a production zone, and wherein an opposing end of each of the plurality of second packers is fluidly coupled to an injection zone. 
     Example 17 
     The system of example 13, wherein the bulkhead manifold of each of the first plurality of annular bypass packers is fluidly coupled to an external bypass conduit extending through one of an isolation zone or an injection zone. 
     Example 18 
     The system of example 13, wherein the second end of each of the first plurality of annular bypass packers is fluidly coupled to the annulus of the wellbore at a production zone. 
     Example 19 
     The system of example 13, wherein the bulkhead manifold of each of the plurality of second packers is fluidly coupled to an external bypass conduit extending through an injection zone, and wherein an opposing end of each of the plurality of second packers is fluidly coupled to a production zone. 
     Example 20 
     The system of example 8, wherein the bulkhead manifold assembly is a first bulkhead manifold, and wherein the second end of the packer comprises a second bulkhead manifold, and wherein the external bypass conduit is a first external bypass conduit, and wherein the second bulkhead manifold is coupled to a second, downhole external bypass conduit. 
     Example 21 
     The system of example 20, wherein the packer comprises a plurality of packers, and wherein each first end of a packer is coupled to a first external bypass conduit extending through an uphole isolation zone and wherein each second end of a packer is coupled to a second external bypass conduit extending into a downhole isolation zone. 
     Example 22 
     A method of providing fluid flow to a wellbore, the method comprising: supplying a fluid to an annulus of a wellbore from a fluid supply source; and supplying fluid to a first end of an annular bypass packer. The annular bypass packer includes: (1) a first conduit extending from the first end of the packer to a second end of the packer; (2) a second conduit adjacent to the first conduit, wherein a portion of the second conduit is formed by an outer surface of the first conduit; and (3) a swelling element surrounding the first conduit and second conduit, wherein the first end of the packer comprises a bulkhead manifold assembly having a transition section forming a fluid coupling from at least one external conduit to the second conduit, and wherein the swelling element is operable to form a seal against a wellbore wall upon exposure to a wellbore fluid. The first end of the packer is fluidly coupled to the fluid supply source via an external bypass conduit. 
     Example 23 
     The method of example 22, wherein the second conduit is fluidly coupled to an injection zone of the wellbore at the second end of the packer. 
     Example 24 
     The method of example 22, wherein the bulkhead manifold comprises a transition portion fluidly coupling the second conduit to an external bypass conduit. 
     Example 25 
     The method of example 22, wherein the first conduit comprises a first tubing segment, and wherein the second conduit is formed by an outer surface of the first tubing segment and an internal portion of a second tubing segment that is joined to the first tubing segment. 
     Example 26 
     The method of example 25, wherein the second tubing segment is seam-welded to the first tubing segment. 
     Example 27 
     The method of example 22, wherein the packer comprises a plurality of first packers, and further comprising a plurality of second packers. 
     Example 28 
     The method of example 27, wherein the bulkhead manifold of each of the plurality of first packers is fluidly coupled to an external bypass conduit extending through a production zone. 
     Example 29 
     The method of example 27, wherein the second end of each of the plurality of first packers is fluidly coupled to an injection zone. 
     Example 30 
     The method of example 27, wherein the bulkhead manifold of each of the plurality of second packers is fluidly coupled to an external bypass conduit extending through a production zone, and wherein an uphole end of each of the plurality of second packers is fluidly coupled to an injection zone. 
     Example 31 
     The method of example 27, wherein the bulkhead manifold of each of the plurality of first packers is fluidly coupled to an external bypass conduit extending through one of an isolation zone and an injection zone. 
     Example 32 
     The method of example 27, wherein the second end of each of the plurality of first packers is fluidly coupled to a production zone. 
     Example 33 
     The method of example 27, wherein the bulkhead manifold of each of the plurality of second packers is fluidly coupled to an external bypass conduit extending through an injection zone, and wherein an uphole end of each of the plurality of second packers is fluidly coupled to a production zone. 
     Example 34 
     The method of example 22, wherein the bulkhead manifold is a first bulkhead manifold, and wherein the second end of the packer comprises a second bulkhead manifold, and wherein the external bypass conduit is a first external bypass conduit, and wherein the second bulkhead manifold is coupled to a second, downhole external bypass conduit. 
     Example 35 
     The method of example 34, wherein the packer comprises a plurality of packers, and wherein each the first end of a packer is coupled to a first external bypass conduit extending through an uphole isolation zone and the second end of each packer is coupled to a second external bypass conduit extending into a downhole isolation zone.