Well Completion System with Grooved Sealing Element

Abstract

A completion system includes a packer mounted on a completion string. The packer has a sealing element with a unitary seal body. The unitary seal body includes a first face at a first end, a second face at a second end, and a wall extending from the first face to the second face. The wall has an exterior surface defining a circumferential groove extending around a circumference of the unitary seal body. The unitary seal body also defines a radial branch channel in the wall extending from an inlet defined in the wall of the unitary seal body, to an outlet defined in the groove. The sealing element also includes a bypass valve arranged in or disposed on the radial branch channel. A pressure line of the system fluidly connects to the inlet of the radial branch of the unitary seal body.

Description

TECHNICAL FIELD

[0001] This disclosure relates to a completion system with grooved sealing elements, and more specifically to grooves of a packer connected to a control line.BACKGROUND

[0002] Some well completions include the installation of multiple packers and valves in one string as an upper completion. Typically, the completions with multiple packers are run-in-hole (RIH) to separate and control the production of different laterals in same well.SUMMARY

[0003] The disclosed systems and methods include a single pressure (control) line connected to an outlet in a groove of a sealing element of a packer. The system tests the seal formed by the sealing element using a port open / close bypass valve could be multi or single cycle. The system and methods may mitigate the damage caused by undiscovered fluid communication between laterals, thereby reducing the risk of uncontrolled commingling of production. Additionally, the operators implementing the systems and methods may more closely monitor the deployed, in-well status of the system which can reduce the need for workover and de-completion and reduce costly repairs.

[0004] In certain aspects, a packer includes a sealing element having a unitary seal body extending from a first end to a second end. The unitary seal body includes a first face at the first end of the unitary seal body, a second face at the second end of the unitary seal body, and a wall extending from the first face to the second face. The wall has an exterior surface defining a circumferential groove extending around a circumference of the unitary seal body. The unitary seal body also includes a central line channel defined in the wall and a radial branch channel defined in the wall. The central line channel extends from an entrance port defined in the first face of the unitary seal body to an exit port defined in the second face of the unitary seal body. The radial branch channel extends from the central line channel to an outlet defined in the groove, The sealing element also includes a bypass valve arranged in or disposed on the radial branch channel of the unitary seal body.

[0005] In some systems, the bypass valve includes a shearing pin with a predetermined shearing pressure.

[0006] Some bypass valves are arranged at or adjacent the outlet of the unitary sealing body.

[0007] In some embodiments, the bypass valve is configured to close at a predetermined pressure.

[0008] The first end of the unitary seal body and the second end of the unitary seal body can define a packer axis. The central line channel can extend parallel to the packer axis. The radial branch channel can extend perpendicular to the packer axis.

[0009] In some embodiments, the radial branch channel includes an inlet defined in the wall of the unitary seal body. The inlet connects to the central line channel between the entrance port and the exit port. The outlet of the radial branch channel and the central line channel can be fluidly connected by the inlet.

[0010] Some sealing elements include an inlet connector arranged in the inlet of the unitary seal body.

[0011] In some cases, the central line channel is sized to receive the central line.

[0012] In some embodiments, the system also includes a packer body extending from a first end of the packer to a second end of the packer. The sealing element can include an interior surface integral with or attached to the packer body.

[0013] In certain aspects, a completion system includes a packer mounted on a completion string and a pressure line fluidly connected to packer. The packer includes a sealing element and a bypass valve. The sealing element has a unitary seal body extending from a first end to a second end. The unitary seal body includes a first face at the first end of the unitary seal body, a second face at the second end of the unitary seal body, and a wall extending from the first face to the second face. The wall has an exterior surface defining a circumferential groove extending around a circumference of the unitary seal body. The unitary seal body has a radial branch channel defined in the wall of the unitary seal body. The radial branch channel extends from an inlet defined in the wall of the unitary seal body, to an outlet defined in the groove. The bypass valve of the sealing element is arranged in or disposed on the radial branch channel. The pressure line of the system is fluidly connected to the inlet of the radial branch of the unitary seal body.

[0014] The unitary seal body can also include a central line channel defined in the wall of the unitary seal body. The central line channel extends from an entrance port defined in the first face of the unitary seal body to an exit port defined in the second face of the unitary seal body. In some cases, the pressure line is a central line arranged in the central line channel of the unitary seal body and the central line extends from the surface, into the unitary seal body. The central line can include a groove connector and the groove connector can mate with an inlet connector of the sealing element to fluidly connect the central line with the outlet of the unitary sealing body.

[0015] Some inlets of the unitary seal body are arranged on an inner surface of the unitary seal body and the inner surface defines an inner volume connected to an interior space of the completion string. Some systems also include a string tool axially translatable within the interior space of the completion string. The string tool can include a wash pipe including the pressure line, a first pressure cup attached to the wash pipe, a second pressure cup attached to the wash pipe, and a circulation port defined in the wash pipe between the first pressure cup and the second pressure cup. The circulation port can be fluidly connected to the pressure line. Some circulation ports of the string tool are arranged in the inner volume of the sealing element and are radially aligned with or connected to the inlet of the unitary sealing body.

[0016] In certain aspects, method includes prompting a pressure pump to apply a first predetermined test pressure to a pressure line of a completion system. The pressure line is fluidly connected to an outlet defined in a circumferential groove of a unitary sealing body of a packer of the system. The method also includes receiving pressure signals from a pressure sensor of the system and determining, based on the received pressure signals, that an exterior surface of the unitary seal body is sealed to a wellbore wall. The method includes prompting the pressure pump to apply a second predetermined shearing pressure to the pressure line.

[0017] In some methods, the pressure line is a central line extending from a surface, through the unitary sealing body of the packer. The central line can connect to a radial branch channel defined in the unitary sealing body of the packer. The packer can include a bypass valve disposed on the radial line and including a shearing pin having a shearing pressure at the second predetermined shearing pressure.

[0018] In some methods, the packer is a first packer, and the system includes a second packer arranged downhole of the first packer. The method also includes prompting a pressure pump to apply a third predetermined test pressure to the pressure line of a completion system. The pressure line can be fluidly connected to a second outlet defined in a second circumferential groove of a second unitary sealing body of the second packer of the system. The method can also conclude receiving second pressure signals from a second pressure sensor of the second packer of the system, determining, based on the received second pressure signals, that a second exterior surface of the second unitary seal body is sealed to the wellbore wall, and prompting the pressure pump to apply a fourth predetermined shearing pressure to the pressure line. In some cases, the pressure line is a central line with a pipe that extends from the surface through the first unitary seal body of the first packer and through the second unitary seal body of the second packer. In some cases, the pressure line is a wash pipe of a translatable tool of the system, the translatable tool is axially movable within a completion string, and the first packer and second packer are arranged on the connection pipeline. Prompting the pressure pump to apply the first predetermined test pressure to the pressure line of the completion system can include aligning a circulation port of the tool with a first inlet of the first radial branch channel defined in the first unitary seal body. In some cases, prompting the pressure pump to apply the third predetermined test pressure to the pressure line of the completion system can include aligning the circulation port of the tool with a second inlet of a second radial branch channel defined in the second unitary seal body.

[0019] The details of one or more embodiments are set forth in the accompanying drawings and the description below. Other features, objects, and advantages will be apparent from the description and drawings, and from the claims.DESCRIPTION OF DRAWINGS

[0020] FIG. 1 is a front view of a completion system with packers having grooved sealing elements and a central line connecting the packers.

[0021] FIG. 2A is a perspective view of a first packer with a first grooved sealing element.

[0022] FIG. 2B is a perspective view of a second packer with a second grooved sealing element.

[0023] FIG. 3A is a cross sectional front view of the first grooved sealing element.

[0024] FIG. 3B is a cross sectional front view of the second grooved sealing element.

[0025] FIGS. 4A-C are cross-sectional front views of the smart completion system in use, confirming the seal between a wellbore wall and the grooved sealing element.

[0026] FIG. 5 is a view of a flowchart of a method for confirming the seals of a smart completion system with a central line.

[0027] FIG. 6 is a front view of a smart completion system with packers having grooved sealing elements.

[0028] FIG. 7 is a view of a string tool of the smart completion system.

[0029] FIG. 8 is a view of the packers with grooved sealing elements mounted on a string.

[0030] FIG. 9 is a view of the string tool inserted into the string and aligned with a first packer.

[0031] FIG. 10 is a view of a flowchart of a method for confirming the seals of a smart completion system with a string tool.

[0032] Like reference symbols in the various drawings indicate like elements.DETAILED DESCRIPTION

[0033] A smart (intelligent) completion system includes packers, for example a first packer and a second packer, each with grooved sealing elements for pressure testing the connection between the sealing elements of the packers and a wellbore wall. The sealing element of each packer includes a unitary seal body which defines a circumferential (e.g., radially extending) groove or recess. The sealing element of the packer defines a branch channel extending from a pressure line, for example a central line, to an outlet located in the groove. When the sealing element is pressed onto a wellbore wall to form a fluidic seal, a testing space is formed between the wellbore wall and the groove. The pressure in the testing space is controlled by pressurizing or depressurizing the pressure line.

[0034] In use, after setting the packers in the well, pressure is applied to the central line and to the outlets of the first and second packers to test the seal made between the packers and a wellbore wall. After any desired tests have been performed on the first packer, the pressure is increased above a first shearing pressure of shearing bypass valve in the first (uphole) packer. This shearing causes the bypass valve in the first packer to close. After any desired tests have been performed on the second packer, the pressure is increased above the shearing pressure of the bypass valve of the second packer. Once sheared, the bypass valve of the second packer closes. The pressure in the central line is then bled off and the seals made between the packers and the wellbore are confirmed.

[0035] The smart completion system can pressure test seals formed between downhole packers and the wellbore using a pressure line that extends to each packer. As such an operator can customize the smart completion during installation so that selective pressure testing of downhole seals can occur. In addition, the disclosed systems can implement a translatable tool that can pressure test any packer-well seal in the multiple packer arrangement. The translatable tool permits a user to pressure test the packers, as needed, without any special considerations of shearing pressures of the shearing pins during installment. The ability to pressure test each seal, during installation of the completion, can result in quicker identification of leaking seals and make those repairs less costly and time consuming since the necessary equipment (e.g., a drilling rig) is still in place when the bad seal is discovered. Additionally, the disclosed systems and methods could increase the well life of the well by promptly correcting and repairing the equipment when a leak exists but is not yet critical.

[0036] FIG. 1 is a front view of a deployed smart completion system 100 arranged in a multilateral wellbore 101. The multilateral wellbore 101 includes a main wellbore 102 extending from the surface (not shown) to a floor (not shown) of the main wellbore 102.

[0037] The completion system 100 includes multiple packers 104 that each have a sealing element 106 with a circumferential groove 108. The multiple packers 104 are mounted onto a string 110. In some cases, the packers are integral with the string or releasably connected to the string. The sealing element 106 of each packer 104 is set and mounted to a wall 112 of the main wellbore 102. When mounted on the wellbore wall 112, the groove 108 and the wellbore wall 112 define a testing space 114 for determining whether the sealing element 108 has made a hydraulic seal capable of withstanding known operating pressures.

[0038] A pressure line connects the testing space 114 to a pressure pump 116. In the system 100, the pressure line in the completion system 100 is a central line 118 exterior to the string 110. In some cases, the central line is arranged in the string or in a wall of the string. The central line 118 includes a pipe 120 that defines an interior central line conduit 122 (FIG. 4A). The pipe 120 of the central line 118 can withstand pressures from about 500 psi to about 20,000 psi, for example about 1,000 psi to about 15,000 psi.

[0039] The pressure pump 116 is operable to increase, decrease, and / or maintain a predetermined pressure in the pressure line. The pressure pump 116 can be arranged at the surface or in the main wellbore 102.

[0040] The string 110 defines an axis 124. The multiple packers 104 are centered on the axis 124 and are distanced from each other along the axis 124. In the system 100, the multiple packers 104 include a first packer 126 and a second packer 128.

[0041] When installed and set, the first and second packers 126, 128 partition the main wellbore 102 into isolated portions. The (vertical) wellbore 102 is divided into a first portion 102a, a second portion 102b down hole of the first portion 102a, and a third portion 102c downhole of both the first portion 102a and the second portion 102b. The first portion 102a extends between a surface or uphole sealing device and the first packer 126. The second portion 102b extends between the first packer 126 and the second packer 128. The third portion 102c of the main wellbore 102 extends from the second packer 128 to a wellbore floor or other downhole sealing device.

[0042] The completion system 100 is arranged in the multilateral wellbore 101 with the main (vertical) wellbore 102 and various lateral wellbores 130. The lateral wellbores 130 connect to the main wellbore 102 so that natural gas and / or hydrocarbons can exit a formation and move uphole to the surface.

[0043] The multilateral wellbore 101 has a first lateral wellbore 132 with a first opening 134 defined in the wellbore wall 112. The first opening 134 of the first lateral wellbore 132 is aligned with and connects into the second portion 102b of the main wellbore 102. The multilateral wellbore 101 also includes a second lateral well 136 with a second opening 138 defined in the wall 112 of the main wellbore 102. The second opening 138 is aligned with and connects into the third portion 102c of the main wellbore 102. In this configuration, the first lateral wellbore 132 is fluidly connected to the second portion 102b of the main wellbore 102 by the first opening 134. The second lateral wellbore 136 is fluidly connected with the third portion 102c of the main wellbore 102 by the second opening 138.

[0044] When the first and second packers 126, 128 are properly sealed to the wellbore wall 112, for example, sealed to the wall 112, the resultant seal is capable of withstanding downhole or uphole pressures from about 500 psi to about 20,000 psi, for example about 1,000 psi to about 15,000 psi. In some systems, the resultant seal and the pipe of the central line are operable to withstand about the same range of pressures.

[0045] In use, the seal between the first packer 126 and the wellbore wall 112 fluidically isolates the first portion 102a of the main wellbore 102 from the second portion 102b of the main wellbore 102. A proper seal between the second packer 128 and the wellbore wall 112 fluidically isolates the second portion 102b of the main wellbore 102 from the third portion 102c of the main wellbore 102. Fluidically isolating the second portion 102b of the main wellbore 102 from the third portion 102c of the wellbore 102 also fluidically isolates the first lateral wellbore 132 from the second lateral wellbore 136.

[0046] The string 110 has a connection end 140 and a free end 142 which define the axis 124. The connection end 140 connects the string 110 to additional tools uphole of the string 110 and to the surface (not shown). The string can be operable to selectively permit or restrict inflow from the first portion of the wellbore, the second portion of the wellbore and / or from the third portion of the wellbore.

[0047] The system 100 also includes a computer system 145 having a controller 147a, one or more processors 147b, a non-transitory computer-readable medium storing instructions executable by the one or more processors 147b to perform operations.

[0048] The operations can include prompting the pressure pump 116 to apply a first predetermined test pressure to the central line 118 (pressure line) of a completion system 100. The pressure applied to the central line 118 also applies to the testing space 114 defined by the groove 108 and the wellbore wall 112.

[0049] Additionally, the computer system 145 is operably connected to pressure sensors 147c arranged in or mounted to at least one of, the pressure pump 116, the central line 118, the central channel 174, the branch channel 192, the bypass valve 198, the outlet 196, and / or the groove 108. The pressure pump 116, the bypass valve 198, the pressure sensors 147c are each operably connected to and controllable by the computer system 145. The pressure sensors 147c are operable to measure or sense a pressure, generate pressure signals indicative of the measured or sensed pressure, and transmit the pressure signals to the computer system 145. The pressure sensors can include a transceiver operable to receive signals and prompts from the computer system.

[0050] The operations also include receiving pressure signals from the pressure sensors 147c of the system 100 and determining, based on the received pressure signals, whether the contact surface 178 forming at least part of the exterior surface 180 of the unitary seal body 106 is sealed to a wellbore wall 112 such that the seal will remain (hold) under wellbore conditions and pressures. Where the pressure applied by the pressure pump 116 is not maintained, the seals may be broken, leaking, or improperly set. If the pressure applied by the pressure pump is maintained in the testing space 114, the computer system 145 can determine that the seal was is proper and will hold under operational conditions. The operations then include prompting the pressure pump 116 to apply a second predetermined shearing pressure to the central line 118 to shear a shearing pin 202, 204 (FIGS. 3A, 3B) of the bypass valves 198a, 198b (FIGS. 3A, 3B).

[0051] FIG. 2A is a perspective view of the first (intermediary, pass-through) packer 126 of the completion system 100. The first packer 126 has a uphole (first) end 144 and a downhole (second) end 146. A packer body 148 extends from the first end 144 to the second end 146 of the packer 104. The uphole end 144 connects to the string 110. The downhole end of the packer can be a free end, unconnected to a downhole tool or pipeline. The packer body 148 is hollow and has an interior surface 150 defining an interior body volume 152. In some cases, the packer is connected to another tool mounted to the string and downhole of the packer to form a string channel.

[0052] A sealing element 106 for contacting and sealing the first packer 126 to the wellbore wall 112 can be mounted to the packer body 148. In some cases, the sealing element is formed or arranged integrally with the packer body.

[0053] In the first packer 126, the sealing element 106 is a pass-through (intermediary, first) sealing element 106a operable to guide or hold of pipes extending through the sealing element 106a while maintaining fluidic isolation between the first portion 102a and the second portion 102b of the wellbore 102. The intermediary sealing element 106a defines a set of uphole (first direction) oriented intake apertures 162 and a set of downhole (second direction) oriented output apertures 163. The intake apertures 162 and output apertures 163 are sized to receive the central line 118 and shaped to seal the central line 118 to the intermediate sealing element 106a.

[0054] The intermediary sealing element 106a includes an intermediary (first, pass-through) unitary seal body 160a. The circumferential groove 108 is defined in the first unitary seal body 160a

[0055] FIG. 2B is a perspective view of the second (terminus, bottom-most) packer 128 of the completion system 100. The second packer 128 is substantially similar to the first packer 126, however, the second packer 128 is a second (terminus) packer 128 that has a terminus (second) sealing element 106b rather than the intermediary sealing element 106a. The terminus sealing element 106b has a solid base devoid of downhole oriented output apertures. Additionally, the central line 118, when arranged in the terminus packer 128, extends only to an0 inlet 194 (FIG. 3B) within the terminus sealing element 106b (FIG. 3B).

[0056] FIG. 3A is a cross-sectional front view of the intermediary (first, pass-through) sealing element 106a with the circumferential groove 108. The intermediary sealing element 106a includes the first (pass-through, intermediary) unitary seal body 160a that extends from a first end 167 of the first unitary seal body 160a to a second end 168 of the first unitary seal body 160a. The first unitary seal body 160a has a first face 170 at the first end 167 of the first unitary seal body 160a and a second (pass-through, intermediary) face 172a at the second end 168 of the first unitary seal body 160a. The second face 172a is oriented away from the first face 170, and towards the second end 146 of the first packer 126 (FIG. 2A). The first face 170 is oriented away from the second face 172a, towards the first end 144 of the first packer 126 (FIG. 2A).

[0057] The first (intermediary, pass-through) barrel (or wall) 176a of the first unitary seal body 160a extends from the first face 170 to the second face 172a. The first barrel 176a has an outer (exterior, radial) face 178. The outer face 178 of the first barrel 176a includes a contact area 180 (contact surface) and the groove 108. The contact area 180 of the barrel 176 forms a seal with objects that are pressed onto at least a portion of the contact area 180. The circumferential groove 108 bisects the contact area 180 to form an uphole (first) contact area 182 (first contact surface) and a downhole (second) contact area 184 (second contact surface).

[0058] The uphole contact area 182 of the first barrel 176a has a first width (diameter), wcs1 and the downhole contact surface 184 of the first barrel 176a has a second width (diameter), wcs2. The groove 108 has a groove width wg1. The first width wcs1 of the uphole contact surface 182 and the second width wcs2 of the downhole contact surface 184 are equal. The groove width wg1 is less than the first width wcs1. The groove wg1 is less than the second width wcs2. The widths wcs2, wcs1, wg1 are taken along paths that are perpendicular to the axis 124, that intersect the axis 124, and that are parallel relative to each other.

[0059] In some systems, widths wcs2, wcs1, wg1 are taken along an axis perpendicular to a seal axis defined by the first face and the second face of the unitary seal body.

[0060] The first unitary seal body 160a has a body height hb1 measured from the first face 170 to the second face 172a (or vice versa). The groove 108 has a groove height hg1. The heights are measured in a direction parallel to the axis 124 along the same plane.

[0061] In some cases, the heights are measured parallel to a seal axis defined between the first face and the second face of the first unitary seal body or to a packer axis defined by the first end and the second end of the first packer.

[0062] The outer face 178, first face 170, and second face 172a connect to form an exterior surface 181 of the unitary seal body 160. The first barrel 176a of the first unitary seal body 160a defines the circumferential groove 108. The groove may be carved into the outer face of the barrel, or the unitary seal body can be shaped to form the groove (recess). The groove 108 extends around a circumference of the first unitary seal body 160a and forms an annular (ring of) space.

[0063] The first unitary seal body 160a defines at least two internal channels defined by internal barrel walls 173 in the first barrel 176a. The first barrel 176a of the first unitary seal body 160a defines a pass-through (first, intermediary) central channel 174a extending parallel to the string axis 124 (FIG. 1). The pass-through central channel 174a can form a portion of the central line channel 118. In some cases, the pass-through central channel sized to receive a pipe defining and / or forming the central line. The internal channels of the first unitary seal 160a can be formed or machined during manufacturing and assembly of the packer. The system can be interconnected and integrated with other packers and the external control lines. The system can also be interconnected and integrated to a surface on the rig site, which can undergo a pressure testing and verification protocol.

[0064] When arranged in the pass-through central channel 174a, the central line 118 seals to the first unitary seal body 160a at a rating sufficient to withstand operational and testing pressures.

[0065] The first face 170 of the first unitary seal body 160a defines an entrance port 188. The entrance port 188 is axially aligned with the intake aperture 162 of the intermediary sealing element 106a. The entrance port 188 is sized to receive the central line 118. The second face 170a of the first unitary seal body 106a defines an exit port 190. The exit port 190 is aligned with the exit aperture 164 (FIG. 4A) of the intermediary sealing element 106a.

[0066] In addition to the pass-through central channel 174a, the first barrel 176a also defines a (radial) branch channel 192 that extends radially away from the axis 124. The (radial) branch channel 192 extends perpendicular to the axis 124 and the intermediary central channel 174a. The branch channel 192 connects to intermediary central channel 174a by an inlet 194 arranged in the internal barrel walls 173 defining the intermediary central channel 174a.

[0067] The inlet 194 can include a connector 195 for engaging the central line 118. The connector 195 is a valve or nozzle. Some inlets include a drill through path or other structure for delivering pressure between the central line channel and the branch channel.

[0068] In some first unitary seal bodies, the inlet is part of the branch channel. In some cases, the inlet is an opening that passively connects the central line to the channel.

[0069] The branch channel 192 extends to an outlet 196 defined in the groove 108. The inlet 194 is arranged closer to the axis 124 than the outlet 196. A first (intermediary, pass-through) bypass valve 198a is arranged in or disposed on the branch channel 192 between the inlet 194 and the outlet 196. In some cases, the first bypass valve is arranged at or adjacent to the outlet. In some cases, the bypass valve is arranged at or adjacent to the inlet.

[0070] The location of the outlet 196 at the groove 108 fluidly connects the pressure pump to an annular (ring-shaped) space 200 defined by the groove 108. The pressure pump 116 is connected to the annular space 200 by the central line 118, the inlet 194, the branch channel 192 (when the intermediary bypass valve 198a is open), and the outlet 196. When the annular space 200 is further bound, for example by the wellbore wall 112, the annular space 200 forms the testing space 114.

[0071] The open or closed state of the intermediary bypass valve 198a controls the fluid connection between the inlet 194 and the outlet 196. In the open position, the radial branch channel 192 fluidly connects the pass-through central channel 174a to the environment external to the first packer 126. When the system 100 is arranged in the main wellbore 102, the pass-through central channel 174a is fluidly connected with the test space 114 via the radial branch channel 192 and the open intermediary bypass valve 198a. In the closed position, the intermediary bypass valve 198a fluidically the central line channel 174a and at least part of the radial branch channel 192 from the environment external to the first packer 126.

[0072] The intermediary bypass valve 198a has a first (intermediary, passthrough) shearing pin 202 that holds the intermediary bypass valve 198a open. The first shearing pin 202 of the intermediary bypass valve 198a of the first packer 126 has a predetermined (known) pressure at which the first shearing pin 202 will fail. When the first shearing pin 202 fails, the valve 198a permanently closes. The permanent closed state of the valve can reduce or prevent future potential well integrity leakage risks.

[0073] FIG. 3B is a cross-sectional front view of the terminus (second) sealing element 106b of the second packer 128 with the circumferential groove 108. The terminus sealing element 106b has a second (terminus) unitary seal body 160b. The second sealing element 106b is substantially similar to the intermediary sealing element 106a, however, the second sealing element 106b does not defined any exit apertures and the second unitary seal body 160b does not define any exit ports in the second end. Rather, a second central channel 174b defined in a second (terminus) barrel 176b, extends from the entrance port 188 defined in the first face 170 to a stop 206 adjacent the inlet 194. The second central channel 174b can form or define a portion of the central line 118. In some cases, the central line is defined by a pipe that is arranged in and sealed to the second central channel 174b.

[0074] The uphole contact surface 182 of the second barrel 176b has a third width (diameter), wcs3 and the downhole contact surface 184 of the second barrel 176b has a fourth width (diameter), wcs4. The groove 108 in the second packer 126 has a second groove width wg2. The third width wcs3 and the fourth width wcs4 are equal. The second groove width wg2 is less than the third width wcs3 and less than the fourth width wcs4. The widths wcs3, wcs4, wg2 are taken along paths that are perpendicular to the axis 124, that intersect the axis 124, and that are parallel relative to each other. In some systems, widths wcs3, wcs4, wg2 are taken along an axis perpendicular to a seal axis defined by the first face and the second face of the unitary seal body.

[0075] The second unitary seal body 160b has a body height hb2 measured from the first face 170 to the second face 172b (or vice versa). The second groove 108 has a second groove height hg2. The heights are measured in a direction parallel to the axis 124 along the same plane. In some cases, the heights are measured parallel to a seal axis defined between the first face and the second face of the second unitary seal body or to a packer axis defined by the first end and the second end of the second packer.

[0076] Additionally, the second unitary seal body 160b defines the branch channel 192 which extends from the inlet 194 to the outlet 196. A second (terminus) bypass valve 198b is arranged in or disposed on the branch channel 192. The second bypass valve 198b in the second packer 128 includes a second shearing pin 204. The second shearing pin has a second predetermined sharing pressure at which the shearing pin fails and the second bypass valve 198b closes.

[0077] The second predetermined shearing pressure of the second shearing pin 204 in the first packer 126 is greater than the first predetermined shearing pressure of the first shearing pin 202 in the first packer 126. In this configuration, the first packer 126 will close the first bypass valve 198a before the second packer 128 will close the second bypass valve 198b. In some systems, the second predetermined shearing pressure is less than or equal to the first predetermined shearing pressure.

[0078] FIG. 4A is a cross-sectional front view of the smart completion system 100 installed in the multilateral wellbore 101 during an all-open phase of a seal pressure test. During a seal pressure test, the completion system 100 tests seals formed between the contact area 180 of multiple packers 104 and the wellbore wall 112. In the system 100, the multiple packers 104 include the first packer 126 and the second packer 128. The second packer 128 is arranged downhole of the first packer 126 in the main wellbore 102. Both the first and second packers are centered on and aligned with the axis 124.

[0079] The first packer and second packer 126, 128 are substantially similar to each other, however, the first packer 126 has a bypass valve 198a with a first shearing pin 202 having a first predetermined shearing pressure whereas the second packer 128 has a bypass valve 198b with a second shearing pin 204 having a second predetermined shearing pressure. Additionally, the central line 118 does not extend past or out of the second end 166 of the terminus sealing element 106b. In the system 100, the first predetermined shearing pressure is less than the second predetermined shearing pressure.

[0080] The intelligent completion system 100 has three phases depending on the state of the first and second bypass valves 198a, 198b: all-open, all-closed, or mixed. In an all-open phase (FIG. 4A), the bypass valves 198a, 198b of the first and second packers 126, 128 are each in the open state because the first and second shearing pins 202, 204 remain intact and unsheared. In the all-open phase, the pressure in the central line 118, and thus the radial branch channels 192 of the first and second packers 126, 128, is less than the first predetermined shearing pressure. In this phase, the operator can pressure test the seals, and in particular, can determine the state of the seal between the first packer 126 and the wellbore wall 112. In the all-open phase, data generated by pressure sensors 147c in each packer can generate and transmit measurements that indicate the failure or success of the first packer 126 or any other packers arranged downhole of the first packer 126.

[0081] FIG. 4B is a cross-sectional front view of the smart completion system 100 installed in the multilateral wellbore 101 during a mixed phase of a seal pressure test. In the mixed phase, the pressure applied by the pressure pump 116 is between the first predetermined shearing pressure and the second predetermined shearing pressure. The first bypass valve 198a is closed isolating the testing space 114 of the first packer 126 from the central line 118 and any pressure conveyed by the pressure pump. Isolation of the testing space 114 of the first packer 126 permits the downhole seals to be tested, for example the seal between the second packer 128 and the wellbore wall 112. The second bypass valve 198b remains open in the mixed status. The first shearing pin 202 of the first packer 126 is sheared and the first bypass valve 198a closed. The second pin 204 remains intact and the second bypass valve remains open. The testing space 114 and / or pressure sensors arranged in the second packer or the central line 118 can generate data that is indicative of the state of the seal between the second packer 128 and the wellbore wall 112.

[0082] FIG. 4C is a cross-sectional front view of the smart completion system 100 installed in the multilateral wellbore 101 during the all-closed phase of a seal pressure test. In an all-closed phase, the pressure generated by the pressure pump 116 is equal to or greater than the second predetermined shearing pressure. Under the heightened pressure, the second shearing pin 204 shears and the second bypass valve 198b closes. In this all-closed phase, the testing spaces 114 defined by the first and second packers 126, 128 with the wellbore wall 112 are each isolated from the central line 118 and do not experience the pressure changes generated by the pressure pump.

[0083] FIG. 5 is a view of a flowchart of a method 250 for confirming the seals of a smart completion system 100 with a central line. The method 250 is described with reference to the system 100, however, the method may be used with any appropriate system. The operators first determine the desired or appropriate number of packers 104 to be used in the completion system 100. The method 250 describes a smart completion with two packers, however, the method could be implemented with one packer or more than two packers 104. Components planned to be place below (downhole) of the bottom-most (terminus) packer are picked up and made up on the surface, then the made-up components are run in hole.

[0084] Next, the operators pick up and make up the series of packers 104 in the string 110 at the surface, starting with the terminus packer. Then, the central lines 118 are connected to the packers and simultaneously run-in-hole with the packers. When running in hole, the equipment is lowered inside the well until top of the equipment is submersed in the well (e.g., in the wellbore, adjacent a well opening). As such, the next piece of equipment can be connected to the previous. Running in hole continues until the series of packers connected by the central line is landed downhole at the same time.

[0085] During installation of the packers 104, the packer first deployed will be the bottom-most packer 104 in the smart completion. As such, the installation of the packers 104 can begin by connecting the central line or a first pipe forming at least part of the central line 118 to the terminus packer 128 such that the central line or first pipe extends uphole relative to the terminus packer 126. The terminus packer and uphold facing first pipe forming at least part of the central line are then set (run into) the wellbore 102 together.

[0086] At the surface, the central line or a second pipe forming at least part of the central line is connected to the intermediary packer 126 such that the central line or second pipe extends uphole relative to the intermediary packer. The intermediary packer 126 is then set uphole of the terminus packer 128. The intermediary packer 126 is arranged atop the central line 118 or first pipe forming at least a part of the central line 118 that was run in with the terminus packer. The exit port of the sealing element of the intermediary packer can be sized to receive and seal an end of the first pipe to connect the second central channel 174b of the terminus packer to the first central channel 174a of the intermediary packer. The packers may be part of the smart completion as per tally to be run in hole.

[0087] After the first and second packers 126, 128 and the central lines 118 are set and connected, the first and second packers 126, 128 are prompted to be set (e.g., anchored and / or sealed to the wellbore walls) by the computer system 145. The sealing elements 106a, 106b engage the contact face 180 of the first and second unitary sealing bodies 160a, 160b, with the wellbore wall 112 to form a seal.

[0088] Once the completion system 100 is landed and the first and second packers 126, 128 are set, the pressure in the central line 118 is increased by the pressure pump to test first packer integrity and confirm no leakage occurs in the formed seals. Where no leakage occurs, the seal is proper.

[0089] To increase the pressure, the computer system 145 prompts the pressure pump 116 to apply a first predetermined test pressure to a pressure line, for example the central line 118. The pressure increase also applies to the radial branch channel 192, outlet 196, and testing space 114 of the first packer 126 and to the radial branch channel 192, outlet 196, and testing space 114 of the second packer 128. Pressure sensors connected to the computer system 145 transmit signals containing pressure data, by a transceiver of the pressure sensors, to a transceiver of the computer system 145. The computer system 145 receives the pressure signals and processes the pressure signal to determine the pressure in the testing space 114 a series of pressures of the testing space 114 over time.

[0090] The computer system 145 (computer subsystem) then determines, based on the received pressure signals, that a contact surface of the unitary seal bodies 160a, 160b is sealed to the wellbore wall 112. For example, the computer system may determine that the pressure in the testing space 114 decreased over time even though the pressure pump was prompted to maintain or hold the pressure at a known or instructed level. This decrease could indicate that one or both of the seals was not properly formed and will not withstand normal operating conditions. In response to a measured decrease in pressure, the operator may replace the packer or attempt to reseal the packer to the wellbore.

[0091] Where the computer system 145 determines that the seal is proper, the computer system 145 prompts the pressure pump to increase the pressure above the first predetermined shearing pressure of the first pin 202 in the first packer 126 to break the first shearing pin 202, close the first bypass valve 198a, and ready the system 100 to pressure test the seal between the wellbore wall 112 and a packer connected to the central line and directly downhole of the first packer 126.

[0092] In the system 100, the second packer 128 is directly downhole of the first packer 126. The pressure pump 116 may maintain the first prompted pressure in the central line 118 or may lower the pressure below the first predetermined shearing threshold during testing of the second packer 128.

[0093] Pressure sensors 147c continue to measure and transmit the pressure signals containing pressure data to the computer system 145. The computer system 145 receives the second pressure signals and can determine whether the seal between the second packer 128 and the wellbore 112 is proper. Once the integrity of the second packer 128 is sufficiently tested, the computer prompts the pressure pump to increase the pressure in the central line 118 to a pressure at or above the second predetermined shearing pressure. At pressure above the second predetermined shearing threshold, the sheering pin 204 shears and the second bypass valve 198b closes.

[0094] When both seals have been tested and approved, or otherwise replaced and approved when testing the replacement packers, the computer system 145 prompts the pressure pump to bleed off the pressure in the central line 118. The central line 118 can then be secured for later use.

[0095] FIG. 6 is a front view of a smart completion system 300 with uniform packers 302 having grooved sealing elements 304. The smart completion system 300 is substantially similar to the system 100, however, the system 300 does not include a central line 118 and the packers 302 are uniform rather than a combination of intermediary and terminus packers 126, 128. Additionally, the system 300 includes a translatable tool 310 (FIG. 7) slidable within the string 309 to connect the pressure pump 116 to the packers 302. A string channel 313 defined by the string 309 is sized to receive the translatable tool 310 (FIG. 7). Each packer sealing element 304 of the packers 302 includes a unitary sealing body 306.

[0096] FIG. 7 is a view of a translatable (string, combo) tool 310 of the smart completion system 100. The translatable tool 310 is insertable into the string 309 and slidable along the axis 124 to align a circulation port 312 of the tool 310 with the inlet 194 of the branch channel 192 defined in a unitary seal body 306 of the grooved sealing element 304 (FIG. 8) of each packer 302 (FIG. 8). The tool 310 moves within the string channel 313 defined in the string 309. The string channel 309 includes the interior body volume 152 of the packer body 148 such that the tool 310 is moveable within the string 309 to align with at least one of the packers 104 mounted to or integral with the string 309.

[0097] The translatable tool 310 includes a pressure line for connecting the pressure pump 116 to the radial branch channel 192. In the system 300, the pressure line is the channel defined in the wash pipe 316. The wash pipe 316 or wash pipe channel 316s define by the wash pipe 316 connects at a first end 318 to the pressure pump (not shown) and at a second end 319 to a sealing arrangement 320. The sealing arrangement includes a first cup 322 arranged between the first end 318 of the wash pipe 316 and the second end 319 of the wash pipe 316. The sealing arrangement 320 also includes a second cup 324 arranged at or on the second end 319 of the wash pipe 316. In some cases, the wash pipe comprises a pressure line or forms a pressure line extending to the circulation port.

[0098] The first and second cups 324 are pressure cups and are separated by a distance d1. The circulation port is defined the wash pipe and has a circulation port diameter dc. The distance d between the cups 322, 324 define an alignment window 326 of the sealing arrangement. In use, the computer system 145 prompts a motor (not shown) to move the alignment window 328 of the tool 310 to align with the inlet 194 of the radial branch channel 192 (FIG. 8). When the alignment window 328 aligns with (e.g., sandwiches) the inlet 194, the pressure pump 116 and the testing space 114 are in fluid connect by the wash pipe, circulation port 312, inlet 194, branch line 192, and the outlet 196. When aligned, the computer system 145 can prompt the pressure pump to increase, decrease, or maintain the pressure to test the seal between wellbore wall 112 and the aligning packer 302.

[0099] In use, the first and second cups 322, 324 have contact surfaces on a radial face 330. When engaged with the walls 325 of a packer body 148 of the packers 302, the first and second cups 322, 234 fluidically isolate the alignment window from the rest of the string channel 303.

[0100] FIG. 8 is a view of the packers 302 with the grooved sealing elements 304 mounted on the string 309. The multiple packers 302 include a first packer 302a and a second packer 302b. The first and second packers 302a, 302b are identical. Each packer 302a, 302b in the multiple packers 302 includes a groove 108 extending circumferentially around the circumference of the unitary seal body 306. The unitary seal body 306 defines a radial branch channel 192 (radial line, branch line) extending from an inlet 194 to an outlet 196. The outlet is arranged radially farther from the string axis 124 as compared to the inlet 194.

[0101] The first and second packers 302a, 302b are integrally connected to the string 309. In this configuration, the interior body volume 152 of the packer body 148 of the first and second packers 302a, 302b at least partially form the string channel 313 through which the tool 310 moves. The inlet 194 of the radial branch channel fluidly connects the interior body volume 152 of the string channel 313 to the outlet 196 and testing space 114 when the packers 302 are mounted on the wellbore wall 112. In some cases, the first and second packers are mounted to the string and the string defines an opening aligned with the inlet of the unitary sealing body of the packer.

[0102] Each packer 302 also includes a bypass valve 198 arranged in or disposed on the radial branch channel 182. The bypass valve 198 of the first packer 302a includes a shearing pin 202. The bypass valve 198 of the second packer 302b includes a shearing pin 204. The shearing pins 202, 204 can have the same predetermined shearing force or different predetermined shearing forces. In some cases, the second packer arranged downhole of the first packer has a lower predetermined shearing pressure than the shearing pin of the first packer.

[0103] In use, the tool 310 aligns with any packer 302 forming the string channel 309, applies pressure to the testing space 114 of the aligned packer through the wash pipe and fluidly connected radial branch channel, then, after confirming the seal, increases the pressure to the predetermined shearing pressure of the shearing pin of the aligned packer. In this configuration, the operator can test individual packers in the string 309 in any order even after uphole packers have been set.

[0104] FIG. 9 is a view of the smart completion system 300 in use to pressure test a seal between the first packer 302a and the wellbore wall 112. The alignment window 238 of the tool 310 is aligned with the first packer 302a in the string channel 303 such that the first cup is arrange uphole of the inlet 194 and the second cup is arranged down hole of the inlet 194. The pressure pump can apply a pressure to the wash pipe and the pressure transfers from the tool 310, to the radial branch channel 192 of the first packer 302a, and into the testing space 114 defined by the groove 108 and the wellbore wall 112. The first and second cups can collapse when being run within the string (e.g., downhole or uphole). In use, an increase in pressure between the first and second cups expands (e.g., inflates, spreads) the first and second cups such that the first and second cups form a seal with the string.

[0105] After confirming the seal can withstand the applied pressures, which can include known operating pressures of about 500 psi to about 20,000 psi, for example about 1,000 psi to about 15,000 psi. The pressure is then released and bled off. The seal is confirmed and the tool 310 is free to move along the axis to another packer in the string.

[0106] The tool 310 can then be moved to any other packer 302 in the system 300, for example the second packer 302b. The tool 310 moves downhole and aligns the alignment window 238 of the tool 310 with the inlet 194 of the second packer 302b. The pressure pump can apply a pressure to the wash pipe and the pressure transfers from the tool 310, to the radial branch channel 192 of the second packer 302b, and into the testing space 114 defined by the groove 108 and the wellbore wall 112.

[0107] FIG. 10 is a view of a flowchart of a method 400 for confirming the seals of a smart completion system with a string tool. The method is described with reference to the system 300, however, the method 400 may be used with any applicable system. The method 500 includes aligning the circulation port of the tool with the inlet of the first branch line defined in the first unitary seal body of the first packer. In some cases, the translatable tool aligns with a second packer arranged downhole of non-pressure tested packer.

[0108] The method also includes prompting the pressure pump 116 to apply a first predetermined test pressure to the wash pipe (pressure line). The wash pipe 312 is fluidly connected to the outlet 196 defined in a circumferential groove 108 of the unitary seal body 304 of a packer 302 of the system 300. The method also includes receiving pressure signals from the pressure sensors of the system and determining, based on the received pressure signals, that an outer surface of the unitary seal body is sealed to a wellbore wall. The method also includes prompting the pressure pump 116 to apply a second predetermined shearing pressure to the pressure line (wash over pipe). Some methods also include prompting the pressure pump 116 to apply the third predetermined test pressure to the pressure line (wash over pipe) by aligning the circulation port of the tool 310 with a second inlet 194 of the second branch line 192 defined in the second unitary seal body 304.

[0109] While the smart completion systems have been described as having at least two fluid channels, some smart completion systems define a fluid circuit operable to flow pressurized fluids within the circuit and to the annular space of the groove.

[0110] In this configuration, the fluid circuit is formed at least by fluid channels in the one or more packers, the pressure line (the central line or translatable tool), and the pressure pump (pressure controlling device). The fluid circuit includes the main channel (pressure line) extending from or connected to the pressure controlling device and a branch channel branching off from the main channel. The radial branch channel is defined in within the barrel of the unitary seal body. The radial branch channel extends to the outlet defined in the exterior surface of the unitary seal body. The outlet is defined in a portion of the exterior surface of the unitary body that also defines or bounds the groove of the unitary seal body.

[0111] The main channel can be defined in the unitary seal body, similar to the smart system 100, described with reference to FIG. 1 and / or can be defined in an interior volume of a string or within walls of a string. The main channel may also or alternatively be defined in a translatable tool, similar to the smart system 300, described with reference to FIG. 6. The main channel can also include a central line with a central channel in the unitary seal body.

[0112] The bypass valve of each sealing element is arranged in or disposed on the branch channel of the unitary seal body of the sealing element of the packer. The bypass valve is operable to close off a connection between the branch channel and outlet (e.g., the environment external to the sealing element, the test space formed between the groove and the wellbore wall,

[0113] The pressure controlling device fluidly connects to the branch channel (radial branch channel) via the main channel to test a seal formed by the unitary seal body. The pressure controlling device is operable to simulate downhole and well operational conditions in the fluid circuit.

[0114] In some embodiments, the unitary seal body, and the pressure line (e.g., the central channel of the unitary seal body or the mesh pipeline of the insertable tool) define fluid channels or conduits in the fluid circuit of the completion system.

[0115] While the system having a pressure pump for controlling the pressure has been described, pipe, some system includes a pressure controlling device operable to increase, decrease, and / or maintain a pressure in the central line, the wash over pipe of the translatable tool, or the main channel of the fluid circuit. The pressure controlling device may be a compressor, pressure generator, depressurizer, pressurizer, or any other appropriate pressure controlling tool.

[0116] While sealing elements with a single bypass valve have been described, some sealing elements include two or more control valves operable to control the fluid connection between the inlet of the radial branch channel and the outlet defined in the groove.

[0117] While a system with a single pass-through packer and a single terminus packer has been described, some systems include two or more pass though packers. The pass-through packers are all arranged uphole of the terminus packer.

Claims

1. A packer comprising:a packer body having a first end couplable to a completion string and a second end, the packer body defining an interior body volume extending from the first end to the second end to pass a fluid through the interior body volume to the completion string; anda sealing element mounted to the packer body comprising:a unitary seal body having a first end to a second end, the unitary seal body comprising:a first face at the first end of the unitary seal body,a second face at the second end of the unitary seal body,a wall extending from the first face to the second face, the wall having an exterior surface defining a circumferential groove extending around a circumference of the unitary seal body;a central line channel defined in the wall, extending from an entrance port defined in the first face of the unitary seal body to an exit port defined in the second face of the unitary seal body; anda radial branch channel defined in the wall of the unitary seal body, the radial branch channel extending from the central line channel to an outlet defined in the circumferential groove; anda bypass valve arranged in or disposed on the radial branch channel within the unitary seal body.

2. The packer according to claim 1, wherein the bypass valve comprises a shearing pin having a predetermined shearing pressure.

3. The packer according to claim 1, wherein the bypass valve is arranged at or adjacent the outlet of the unitary seal body.

4. The packer according to claim 1, wherein the bypass valve is configured to close at a predetermined pressure.

5. The packer according to claim 1, wherein the first end of the unitary seal body and the second end of the unitary seal body define a packer axis.

6. The packer according to claim 5, wherein the central line channel extends parallel to the packer axis.

7. The packer according to claim 5, wherein the radial branch channel extends perpendicular to the packer axis.

8. The packer according to claim 1, wherein the radial branch channel comprises an inlet defined in the wall of the unitary seal body, wherein the inlet connects to the central line channel between the entrance port and the exit port.

9. The packer according to claim 8, wherein the outlet of the radial branch channel and the central line channel are fluidly connected by the inlet.

10. The packer according to claim 8, wherein the sealing element includes an inlet connector arranged in the inlet of the unitary seal body.

11. The packer according to claim 1, wherein the central line channel is sized to receive a pipe defining the central line channel.

12. (canceled)13. The packer according to claim 1, wherein the sealing element comprises an interior surface integral with or attached to the packer body.

14. A completion system comprising:a packer mounted on a completion string, the packer comprising:a sealing element comprising:a unitary seal body extending from a first end to a second end, the unitary seal body comprising:a first face at the first end of the unitary seal body,a second face at the second end of the unitary seal body,a wall extending from the first face to the second face, the wall having an exterior surface defining a circumferential groove extending around a circumference of the unitary seal body;a central line channel defined in the wall of the unitary seal body, the central line channel extending from an entrance port defined in the first face of the unitary seal body to an exit port defined in the second face of the unitary seal body; anda radial branch channel defined in the wall of the unitary seal body, the radial branch channel extending from an inlet defined in the wall of the unitary seal body, to an outlet defined in the circumferential groove; anda bypass valve arranged in or disposed on the radial branch channel; anda pressure line fluidly connected to the inlet of the radial branch channel of the unitary seal body, wherein the pressure line is a central line arranged in the central line channel of the unitary seal body, wherein the central line extends from the exterior surface, into the unitary seal body, wherein the central line comprises a groove connector, and wherein the groove connector mates with an inlet connector of the sealing element to fluidly connect the central line with the outlet of the unitary seal body.

15. The completion system according to claim 19, wherein the unitary seal body further comprises a central line channel defined in the wall of the unitary seal body, the central line channel extending from an entrance port defined in the first face of the unitary seal body to an exit port defined in the second face of the unitary seal body.

16. The completion system according to claim 15, wherein the pressure line is a central line arranged in the central line channel of the unitary seal body, wherein the central line extends from the exterior surface, into the unitary seal body.

17. The completion system according to claim 16, wherein the central line comprises a groove connector, wherein the groove connector mates with an inlet connector of the sealing element to fluidly connect the central line with the outlet of the unitary seal body.

18. The completion system according to claim 14, wherein the inlet of the unitary seal body is arranged on an inner surface of the unitary seal body, wherein the inner surface defines an inner volume connected to an interior space of the completion string.

19. A completion system comprising:a packer mounted on a completion string, the packer comprising:a sealing element comprising:a unitary seal body extending from a first end to a second end, the unitary seal body comprising:a first face at the first end of the unitary seal body,a second face at the second end of the unitary seal body,a wall extending from the first face to the second face, the wall having an exterior surface defining a circumferential groove extending around a circumference of the unitary seal body; anda radial branch channel defined in the wall of the unitary seal body, the radial branch channel extending from an inlet defined in the wall of the unitary seal body to an outlet defined in the circumferential groove; anda bypass valve arranged in or disposed on the radial branch channel;a pressure line fluidly connected to the inlet of the radial branch channel of the unitary seal body; anda string tool axially translatable within an interior space of the completion string, wherein the string tool comprises:a wash pipe comprising the pressure line;a first pressure cup attached to the wash pipe;a second pressure cup attached to the wash pipe; anda circulation port defined in the wash pipe between the first pressure cup and the second pressure cup, the circulation port fluidly connected to the pressure line.

20. The completion system according to claim 19, wherein the circulation port of the string tool is arranged in an inner volume of the sealing element and is radially aligned with or connected to the inlet of the unitary seal body.

21. A method comprising:prompting a pressure pump to apply a first predetermined test pressure to a pressure line of a completion system, wherein the pressure line is fluidly connected to an outlet defined in a circumferential groove of a unitary seal body of a packer of the completion system;receiving pressure signals from a pressure sensor of the completion system;determining, based on the received pressure signals, that an exterior surface of the unitary seal body is sealed to a wellbore wall; andprompting the pressure pump to apply a second predetermined shearing pressure to the pressure line.

22. The method according to claim 21, wherein the pressure line is a central line extending from a surface, through the unitary seal body of the packer.

23. The method according to claim 22, wherein the central line connects to a radial branch channel defined in the unitary seal body of the packer, wherein the packer comprises a bypass valve disposed on the radial branch channel and comprising a shearing pin having a shearing pressure at the second predetermined shearing pressure.

24. The method according to claim 21, wherein the packer is a first packer and the unitary seal body is a first unitary seal body, and the completion system comprises a second packer arranged downhole of the first packer, the second packer comprising a second unitary seal body.

25. The method according to claim 24, the method further comprising:prompting the pressure pump to apply a third predetermined test pressure to the pressure line of the completion system, wherein the pressure line is fluidly connected to a second outlet defined in a second circumferential groove of the second unitary seal body of the second packer of the completion system;receiving second pressure signals from a second pressure sensor of the second packer of the completion system,determining, based on the received second pressure signals, that a second exterior surface of the second unitary seal body is sealed to the wellbore wall; andprompting the pressure pump to apply a fourth predetermined shearing pressure to the pressure line.

26. The method according to claim 25, wherein the pressure line is a central line comprising a pipe that extends from a surface through the first unitary seal body of the first packer and through the second unitary seal body of the second packer.

27. The method according to claim 25, wherein the pressure line is a wash pipe of a translatable tool of the completion system, wherein the translatable tool is axially movable within a completion string, wherein the first packer and second packer are arranged on the completion string.

28. The method according to claim 27, wherein prompting the pressure pump to apply the first predetermined test pressure to the pressure line of the completion system comprises aligning a circulation port of the translatable tool with a first inlet of a first radial branch channel defined in the first unitary seal body.

29. The method according to claim 28, wherein prompting the pressure pump to apply the third predetermined test pressure to the pressure line of the completion system comprises aligning the circulation port of the translatable tool with a second inlet of a second radial branch channel defined in the second unitary seal body.

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