Patent ID: 12252952

DESCRIPTION OF SOME EXAMPLE IMPLEMENTATIONS

The description that follows includes example systems, methods, techniques, and program flows that embody implementations of the disclosure. However, it is understood that this disclosure may be practiced without these specific details. In other instances, well-known instruction instances, protocols, structures, and techniques have not been shown in detail in order not to obfuscate the description.

Overview

A clamshell-style packer, as described below, may be used with one or more expandable screens in a wellbore. The clamshell packer may be clamped over a non-compliant region of a base pipe string (or other tubular) to which the expandable screens may not extend. The clamshell packer may prevent sand ingress into the wellbore at this non-compliant region. The clamshell packer may be coupled over a base pipe coupling, after the coupling is made up to the next base pipe, for example, at a surface of the wellbore by on-site personnel. The clamshell packer design allows the packer to be installed over the handling space previously used to make up the base pipe.

To provide zonal isolation in the wellbore, the clamshell packer may be comprised of a reactive, non-elastomeric material such as a metal or metal alloy which is configured to expand in the presence of brine. The expandable material may undergo a chemical reaction to form a reaction product (iron oxide, metal hydroxides, etc.) which may expand the clamshell packer in an annular space of the wellbore. Magnesium may be used to illustrate the volumetric expansion of the reactive metal as it undergoes reaction with the reaction-inducing fluid. The clamshell packer may expand to fill an adjacent, irregular void space such as an open-hole wellbore, thus providing a seal against the wellbore where the expandable screens typically may not reach.

Example Well System

An example well system is now described.FIG.1is a cross-sectional diagram depicting an example well system comprising expandable screen systems, according to some implementations. A well system100may comprise a wellbore112which intersects a subsurface formation120. The wellbore112may include a vertical section114(which is at least partially cemented with a casing string116) and a horizontal section118. The horizontal section118may be an open-hole section of the wellbore112. Other wellbore configurations may also be suitable.

Positioned within the wellbore112and extending from the surface is a tubing string122which provides a conduit for formation fluids to travel from the subsurface formation120to the surface and for stimulation fluids to travel from the surface to the subsurface formation120. The tubing string122may include one or more expandable screen systems125. The expandable screen systems125may comprise sections of expandable metal screens used to mitigate the migration of unconsolidated reservoir sands or other solids into the wellbore112. Thus, fluids from a reservoir within the subsurface formation120may be produced without introducing solids into the tubing string122. In some implementations, the expandable screen systems125may be comprised of materials other than metal.

The expandable screen systems125, as shown, are depicted in an inactive state to allow for deployment into the wellbore112. However, the expandable screen system125may be actuated to expand and create a sealing interface with the wellbore112. For example, the expandable screen system125may be actuated to expand via a hydraulic system, although various mechanical and electrical methods of actuation may be utilized.

The expandable screen systems125may be disposed on and span sections of the tubing string122. At non-compliant sections of the tubing string122, such as tubing joints comprising tubing couplings115, the expandable screen systems125may not be present. These non-compliant sections, such as those at the tubing couplings115, may introduce various production hazards. For example, sand migration from the subsurface formation120may occur over the tubing couplings115and other non-compliant regions where the screens are not emplaced for sand mitigation. At these non-compliant sections and proximate to the tubing couplings115, a flow of fluids carrying sand and other abrasives from the subsurface formation120may be produced into the tubing string122. The abrasives may induce hot spotting and erosion at the edges of the expandable screen systems125, causing eventual failure of the expandable screen systems125.

The expandable screen systems125may be configured to expand and eliminate an annular gap between the expandable screen systems125in their retracted state and a surface of a wellbore112. The expandable screen systems125, when expanded, may provide positive compliant sand control. Hydraulic activation pressure may radially extend the expandable screen systems125to conform to a geometry of the wellbore112. The expandable screen systems125may be used in place of, for example, a gravel-pack or similar operation.

The well system100may further comprise surface equipment128. The surface equipment128may comprise a wellhead, a choke, one or more production vessels, a power generator, a compressed air unit, and other items of equipment. In some implementations, the surface equipment128may be used to actuate and expand the expandable screen systems125.

Example Assembly

FIG.2Ais a first schematic diagram200depicting an example tubing coupling between screen joints, according to some implementations.FIG.2Amay be described with reference toFIG.1. A tubing string201may comprise a tubular and may include at least a coupling205between sections of tubing. On either side of the coupling205(and beyond a handling space typically between 6-36 inches in length) may reside a joint of an expandable screen203. The expandable screens203may be similar to the expandable screen system125ofFIG.1. While depicted from a side-view, the expandable screens203may be annularly disposed around the tubing string201. The tubing string201, expandable screens203, and tubing coupling205may not be depicted to scale. The schematic diagram200may depict the tubing string201, screens203, and coupling205at a rig setting or similar surface environment prior to being deployed into a wellbore. For example, a base pipe thread between the expandable screens203may be joined together at the coupling205by a rig floor crew, although other methods of assembly may be utilized.

FIG.2Bis a second schematic diagram210depicting an example tubing coupling between screen joints comprising a connection line, according to some implementations.FIG.2Bmay be described with reference toFIG.2A. The schematic diagram210depicts a side-view of a tubing string211. The tubing string211may be similar to the tubing string201, the expandable screens213may be similar to the expandable screens203, and a coupling215may be similar to the coupling205. In addition to the configuration described inFIG.2A, the schematic diagram210may include a connection line217between screen joints. For example, a hydraulic line, electric line, fiber optic line, etc. may be used as the connection line217between the expandable screens213. However, the connection line217is not limited to the above three examples. The connection line217may be conveyed through multiple screen sections and may extend to the surface.

FIG.2Cis a third schematic diagram220depicting an example tubing coupling between screen joints comprising a connection line and a clamshell packer, according to some implementations.FIG.2Cmay be described with reference toFIG.2B. The schematic diagram220depicts a side-view of a tubing string221. The tubing string221may be similar to the tubing string211, the expandable screens223may be similar to the expandable screens213, a coupling225may be similar to the coupling215, and a connection line227may be similar to the connection line217. The schematic diagram220further includes a clamshell-style (“clamshell”) packer229secured around the tubing (base pipe, tubular, etc.)221. The clamshell packer229may be installed at the surface around the tubing coupling225and the connection line227. The clamshell packer229may comprise an outer diameter of an acceptable clearance to run into the wellbore with the expandable screens223in their retracted position.

FIG.3Ais a schematic diagram depicting an example clamshell packer, according to some implementations.FIG.3Amay be described with reference toFIG.2C. A clamshell packer300may be comprised of two halves straddling a base pipe coupling via one or more bolts303. In some implementations, the clamshell packer300may be secured around a coupling (or other non-compliant section between screens) via one or more straps. The clamshell packer300may also be configured to cover the blank handling space at box and pin ends of screen joints, which may be similar to the expandable screens223. The clamshell packer may comprise a primary opening301which may be configured to house a portion of a tubing joint. The clamshell packer300may comprise a secondary opening305configured to house a connection line which may be similar to the connection line217,227. In some implementations, the clamshell packer300may be designed to allow flow tubes, shunt jumper tubes, or other lines to pass through the secondary opening305.

In some implementations, the clamshell packer300may be comprised of a non-elastomeric, expandable (also referred to as swellable or reactive) metal or metal alloy configured to expand via a chemical reaction. For example, the clamshell packer300may be comprised of metals including, but not limited to, magnesium, calcium, aluminum, tin, zinc, beryllium, barium, manganese, or any combination thereof. Preferred metals may include magnesium, calcium, and aluminum. The metal may be configured to swell in the presence of a certain type of fluid, such as a brine.

In other implementations, the clamshell packer300may be comprised of expandable metal alloys including, but not limited to, alloys of magnesium, calcium, aluminum, tin, zinc, beryllium, barium, manganese, or any combination thereof. Preferred metal alloys may include alloys of magnesium-zinc, magnesium-aluminum, calcium-magnesium, or aluminum-copper. In some examples, the metal alloys may comprise alloyed elements that are not metallic. Examples of these non-metallic elements may include, but are not limited to, graphite, carbon, silicon, boron nitride, etc. In some implementations, the metal is alloyed to increase reactivity and/or to control oxide formation. In some implementations, the bolts303may be comprised of similar material to the clamshell packer300, although in other implementations the bolts may be comprised of steel or other non-reactive materials.

In other implementations, the metal alloy used for the clamshell packer300may be alloyed with a dopant metal that promotes corrosion or inhibits passivation. The dopant metal may increase the formation of hydroxides when the clamshell packer300reacts with a wellbore fluid. Examples of dopant metals to be used for the clamshell packer300may include, but are not limited to, nickel, iron, copper, carbon, titanium, gallium, mercury, cobalt, iridium, gold, palladium, or any combination thereof.

FIG.3Bis a cross-sectional diagram depicting a side view of the example clamshell packer, according to some implementations.FIG.3Bmay be described with reference toFIG.3A. A half clamshell310may comprise a primary opening311which may be similar to the primary opening301ofFIG.3A. The half clamshell310may also comprise a secondary opening315which may be similar to the secondary opening305. The secondary opening305may be configured as a pass-through for a connection line such as the connection line227.

Example Clamshell Packer Operation

FIG.4Ais a first illustration depicting an example tubing string proximate to a subsurface formation, according to some implementations. A wellbore450may comprise a tubing string401proximate to a subsurface formation420at a target depth. The tubing string401may comprise a coupling405and expandable screens403disposed around the tubing string401and flanking the sides of a non-compliant area over the coupling405. A clamshell packer409may be installed over the coupling405between the expandable screens403. In some implementations, the expandable screens403may be expandable hydraulic screens. The clamshell packer409may allow a connection line407to pass through. The expandable screens403may be configured in a retracted position while being conveyed to a target site.

FIG.4Bis a second illustration depicting an example tubing string411proximate to a subsurface formation430, according to some implementations. A wellbore460may comprise the tubing string411, coupling415, subsurface formation430, connection line417, and clamshell packer419may be similar to the tubing string401, coupling405, subsurface formation420, connection line407, and clamshell packer409ofFIG.4A. However, the expandable screens413ofFIG.4Bare actuated to expand and make contact with the subsurface formation430. A hydraulic pressure may be applied through the tubing string411to activate, for example, the expandable screens413to become compliant (in contact) with an open hole section of the subsurface formation430. In some implementations, the expandable screens413may be expanded by pressurizing the tubing string411. The tubing string411may comprise ports (not depicted) that allow fluid to expand the expandable screens413. In other implementations, the connection line417may comprise a hydraulic line which may be used to supply pressure to subsequent expandable screens413along the tubing string411. The clamshell packer419may also be actuated to expand to make contact with the subsurface formation430, as further discussed in the description ofFIG.4C.

FIG.4Cis a third illustration depicting an example tubing string421proximate to a subsurface formation440, according to some implementations. A wellbore470may comprise the tubing string421, coupling425, subsurface formation440, connection line427, and expandable screens423may be similar to the tubing string411, coupling415, subsurface formation430, connection line417, and expandable screens413ofFIG.4B. However, a clamshell packer429may be configured to swell and expand under certain conditions to make contact and form a seal against the subsurface formation440. This swelling is achieved by the clamshell packer429increasing in volume. This increase in volume corresponds to an increase in the clamshell packer's annular volume. When expanded, the clamshell packer429may mitigate hot spotting and sand migration at edges of the expandable screens423. In some implementations, the clamshell packer429may be comprised of similar materials to the clamshell packer300. The clamshell packer429may be configured to swell and close the gaps in irregular surfaces such as an open hole wellbore drilled into the subsurface formation440. For example, the clamshell packer429may be used to form a seal between any adjacent surfaces in the wellbore including, but not limited to, various conduits, formation surfaces, cement sheaths, downhole tools, etc. For example, the clamshell packer429may be configured to swell to form a seal between the outer diameter of a conduit such as the tubing string421and a surface of the subsurface formation440. Alternatively, the clamshell packer429may be used to form a seal between the outer diameter of a conduit such as the tubing string421and a cement sheath (e.g., a casing). As another example, the clamshell packer429may be used to form a seal between the outer diameter of one conduit and the inner diameter of another conduit (which may be the same or different). A plurality of clamshell packers429may be used along multiple couplings425of a tubing string421. In some implementations, the clamshell packer429may be configured to swell and anchor a lower completion system in place. The clamshell packer429may also create zonal isolation between expanded screen systems in an open hole wellbore. It is to be understood that the clamshell packer429may be used to form a seal between any adjacent surfaces in the wellbore and the disclosure is not to be limited to the explicit examples disclosed herein.

As described above, the clamshell packer429may be comprised of a reactive metal configured to react with a brine or similar saline solution. The brine may be selected as a wellbore fluid into which the clamshell packer429and tubing string421are conveyed. For example, the brine which reacts with the clamshell packer429may include, but is not limited to, saltwater (e.g., water containing one or more salts dissolved therein), saturated saltwater (e.g., saltwater produced from a subterranean formation), seawater, fresh water, or any combination thereof. Generally, the brine may be from any source. The brine may be a monovalent brine or a divalent brine. Suitable monovalent brines may include, for example, sodium chloride brines, sodium bromide brines, potassium chloride brines, potassium bromide brines, and the like. Suitable divalent brines may include, for example, magnesium chloride brines, calcium chloride brines, calcium bromide brines, and the like. In some implementations, the salinity of the brine may exceed 10%. One of ordinary skill in the art, with the benefit of this disclosure, should be readily able to select a brine for a chosen application.

In some implementations, the brine may be added to wellbore470to replace an initial wellbore fluid. For example, an oil-based mud (OBM) or similar unreactive wellbore fluid with the clamshell packer429may be used when conveying the tubing string421and clamshell packer429to a target depth or location. Once in place, the OBM may be displaced by reactive brine pumped into the wellbore470, thus inducing swelling of the clamshell packer429.

The clamshell packer429, when expanded, may be comprised of non-elastomeric materials that do not possess elasticity, and therefore, irreversibly swell when contacted with a brine. Thus, once expanded, the clamshell packer429may not return to its original size or shape even after the brine is removed. In implementations comprising an elastomeric binder dispersed within the reactive material of the clamshell packer, the elastomeric binder may return to its original size or shape; however, any expandable metal dispersed therein would not.

In some implementations, the clamshell packer429may be coated with one or more layers of coatings to alter a reaction time with a brine downhole. Thus, the coatings may either hasten or slow a reaction rate of the expandable metal of which the clamshell packer429comprises. The clamshell packer429may reasonably reach full expansion (to create a scaling interface), without coatings or other alterations, within a range spanning a few hours to one month. The expandable screens423, however, may expand to contact the subsurface formation440within minutes. While the clamshell packer429may take longer to reach full expansion and create a seal in the wellbore470, completions operations (or other downhole operations) may not be delayed by the slower expansion. Erosion via abrasive invasion inflicts damage on timeframes spanning multiple months to years-thus, abrasion via sand ingress during the clamshell packer's expansion may not cause substantial operational distress to the expandable screens423.

The expansion rate (reaction rate of the clamshell packer) may be altered via changes to the concentration of the selected brine, via the temperature proximate to the clamshell packer429, and, as described above, various coatings used on the clamshell packer429. In some implementations, a reaction rate of the clamshell packer429with a brine may be hastened by increasing a surface area of the clamshell packer429. For example, slits or grooves may be cut into an outward-facing surface of the clamshell packer429that contacts the subsurface formation440. Prior to making contact with the subsurface formation440and forming a seal, the clamshell packer429may be in contact with a reactive brine, and the slits/grooves may increase a surface area of the clamshell packer in contact with the brine, thus increasing the reaction rate between the clamshell packer and the brine.

To limit expansion during transit to a target location in the wellbore, the clamshell packer may comprise a coating layer with a variable corrosion rate when exposed to a wellbore fluid, thus acting as a delay trigger that postpones the reaction of the expandable metal/alloy. Thus, the coating may delay hydrolyzation of the clamshell packer429until a predetermined amount of time has lapsed. As the coating layer is compromised, the expandable material underneath may expand to create a seal. This delay provides time to deploy and position the clamshell packer429to a target location within the wellbore.

In other implementations, a temperature of the wellbore fluid may be used to hasten or delay the expansion of the clamshell packer429. For example, the chemical reaction of the clamshell packer429with the wellbore fluid may be delayed by flowing fluid through an annulus of the wellbore470during expansion of the clamshell packer429. The flow of fluid over the clamshell packer429may decrease the temperature in the wellbore, thus slowing the chemical reaction (and therefore expansion) of the clamshell packer429. In other implementations, the reaction may be hastened by shutting in the wellbore or otherwise halting fluid flow, thereby increasing a downhole temperature in the wellbore470.

The coating on the clamshell packer429may be configured to react with a wellbore fluid (such as a brine) and corrode within a predetermined amount of time to allow the wellbore fluid to contact and hydrolyze the clamshell packer429. It is understood that given enough time, many types of materials have a natural rate of corrosion when exposed to a wellbore fluid environment. However, as used herein, “a predetermined amount of time” means a period of time that is less than a natural rate of corrosion and is one where the selection and/or application of the coating to the clamshell packer429is made to provide a coating layer that corrodes within a selected period of time during which a well completion, workover, or other operation is completed. For example, the predetermined amount of time may range from several hours up to two months. The amount of time delay in corrosion may be based on one or more physical characteristics of the material comprising the coating layer. For example, the corrosion rate may be based on the permeability of the coating, the type of material(s) used in the coating layer, the porosity of the coating, or any combination thereof. In some implementations, the clamshell packer429may comprise multiple coatings of different materials, as explained in further detail below.

In some implementations, the clamshell packer429may comprise a coating composed of a metal, a ceramic, an organic compound, a polymer, or any combination thereof. In implementations where the coating is a metal, the metal may comprise nickel, gold, silver, titanium, chrome, or a combination thereof. Example ceramic coatings for use on the clamshell packer429may comprise zirconium dioxide or other ceramic materials having similar properties. Example organic coatings may include sorbitan monooleate, glycerin monoricinoleate, sorbitan monoricinoleate, sorbitanmonotallate, pentaerythritol monoricinoleate, sorbitan monoisostearate, glycerol monostearate, sorbitan monostearate, or mixtures thereof. In other implementations, a strike or flash, which is a known plating technique, may initially be placed on the reactive metal comprising the clamshell packer429. This plating layer forms a strong bond to the base metal and may allow for thicker layers of coating(s) to be quickly applied.

As mentioned above, the clamshell packer429may be coated with one or more polymers. For example, a polymer coating on the clamshell packer429may be comprised of rubber, epoxy, plastics, such as polylactic acid, poly (glycolic acid), low density polyethylene, high density polyethylene, polypropylene, or urethane plastic. In some implementations, the polymer comprises a relatively high crystalline polymer that is substantially impermeable to wellbore fluid at lower temperatures. However, at elevated temperatures, the polymer may become substantially permeable to a wellbore fluid when heated to a crystallization temperature of the polymer. In some implementations, the clamshell packer429may comprise a polymer coating with a permeability that changes with time. In such implementations, increasing amounts of wellbore fluid (water, brine, etc.) may enter, resulting in hastened destruction of the barrier coating layer. Thus, a more rapid transition from “no expansion” to “rapid expansion” of the clamshell packer429may be achieved.

The connection line427may include, but is not limited to, a hydraulic line, an electric line, or a fiber optic cable. The connection line427may, in some implementations, be used to verify that the clamshell packer429has expanded. For example, to verify that the clamshell packer429has expanded to fill a void in the wellbore470, the connection line427may comprise a fiber optic cable coupled to a computer at the surface and configured to perform distributed temperature sensing (DTS) along the tubing string421. The clamshell packer429may produce a substantial amount of heat when reacting with a brine in the wellbore470, and this heat may be sensed by a DTS system. In other implementations, the connection line427may utilize an electric line. The electric line may apply a voltage to the clamshell packer429via a downhole power generation source or via a surface power unit to induce galvanic corrosion of the clamshell packer429, thus increasing its rate of expansion.

Example Flowchart

FIG.5is a flowchart depicting example operations for use of the clamshell packer, according to some implementations. Operations of a method500may be performed in part by software, firmware, hardware, or a combination thereof. Such operations are described with reference toFIGS.1-4. However, such operations may be performed by other systems or components. The operations of the method500begin at block501.

At block501, the method500includes clamping the clamshell packer229around a coupling225of the tubing string (or similar tubular)221. This may be done at the surface by a rig crew or other on-site personnel. The clamshell packer's design may be configured to clamp over the coupling225and a handling space on the tubular used by the rig crew to create a threaded connection between the two joints of pipe. Flow progresses to block503.

At block503, the method500includes deploying the clamshell packer409with the tubular (tubing string)401to a target position in the wellbore450, wherein the wellbore comprises a first wellbore fluid. In some implementations, the wellbore fluid may comprise a brine configured to chemically react with the clamshell packer409. In other implementations, the wellbore450may comprise a wellbore fluid that is non-reactive with the clamshell packer429. Thus, to induce an expansion of the clamshell packer to form an annular seal within the wellbore450, the non-reactive fluid (e.g., oil-based mud) may be displaced by a brine solution pumped downhole. Flow progresses to block505.

As block505, the method400includes inducing an expansion of the clamshell packer429to form an annular seal with the wellbore470. In some implementations, this expansion may be hastened by increasing a surface area of the clamshell packer429, increasing a salinity of the wellbore fluid, increasing a downhole temperature of the wellbore470, supplying power to the clamshell packer429to induce galvanic corrosion, etc. Flow of the method500ceases.

EXAMPLE IMPLEMENTATIONS

Implementation 1: A clamshell packer for use in a wellbore proximate to a subsurface formation, the clamshell packer comprising: an expandable non-elastomeric material and configured to annularly envelop a non-compliant portion of a tubular in the wellbore, the non-compliant portion between one or more expandable screens.

Implementation 2: The clamshell packer of Implementation 1, wherein the clamshell packer comprises a first sealing element and a second sealing element, wherein the second sealing element is configured to couple to the first sealing element to form the clamshell packer.

Implementation 3: The clamshell packer of any one or more of Implementations 1-2, wherein the clamshell packer is configured to expand and form a sealing interface with the wellbore via a chemical reaction with a reactive wellbore fluid in the wellbore, wherein the reactive wellbore fluid is a brine.

Implementation 4: The clamshell packer of any one or more of Implementations 1-3, wherein the expandable non-elastomeric material comprises one of an expandable metal and an expandable metal alloy configured to react with the reactive wellbore fluid.

Implementation 5: The clamshell packer of any one or more of Implementations 1-4, wherein the clamshell packer includes one or more layers of coating, wherein the one or more layers of coating are configured to alter a reaction rate of the chemical reaction.

Implementation 6: The clamshell packer of any one or more of Implementations 1-5, wherein the clamshell packer comprises one or more grooves, wherein the one or more grooves are configured to increase a surface area of the clamshell packer, and wherein the increased surface area increases a reaction rate with the reactive wellbore fluid.

Implementation 7: An annular sealing system for use in a wellbore proximate to a subsurface formation comprising: a tubular; one or more expandable screens coupled to the tubular; and a clamshell packer including an expandable non-elastomeric material and configured to annularly envelop a non-compliant portion of the tubular between the one or more expandable screens.

Implementation 8: The annular sealing system of Implementation 7, wherein the clamshell packer comprises a first sealing element and a second sealing element, wherein the second sealing element is configured to couple to the first sealing element to form the clamshell packer.

Implementation 9: The annular sealing system of any one or more of Implementations 7-8, wherein the clamshell packer is configured to expand and form a sealing interface with the wellbore via a chemical reaction with a reactive wellbore fluid in the wellbore, wherein the reactive wellbore fluid is a brine.

Implementation 10: The annular sealing system of any one or more of Implementations 7-9, wherein the expandable non-elastomeric material comprises one of an expandable metal and an expandable metal alloy configured to react with the reactive wellbore fluid.

Implementation 11: The annular sealing system of any one or more of Implementations 7-10, wherein the clamshell packer includes one or more layers of coating, wherein the one or more layers of coating are configured to alter a reaction rate of the chemical reaction.

Implementation 12: The annular sealing system of any one or more of Implementations 7-11, wherein the non-compliant portion of the tubular includes a base pipe coupling.

Implementation 13: The annular sealing system of any one or more of Implementations 7-12, further comprising a connection line configured to pass through an opening in the clamshell packer, wherein the connection line is one of a hydraulic line, an electrical line, and a fiber optic cable.

Implementation 14: The annular sealing system of any one or more of Implementations 7-13, wherein the clamshell packer comprises one or more grooves, wherein the one or more grooves are configured to increase a surface area of the clamshell packer, and wherein the increased surface area increases a reaction rate with the reactive wellbore fluid.

Implementation 15: A method for deploying a sealing apparatus into a wellbore formed in a subsurface formation, the method comprising: clamping a clamshell packer including an expandable non-elastomeric material around a coupling of a tubular; deploying the clamshell packer with the tubular to a target position in the wellbore, wherein the wellbore comprises a first wellbore fluid; and inducing an expansion of the clamshell packer to form an annular seal with the wellbore.

Implementation 16: The method of Implementation 15, further comprising: displacing the first wellbore fluid with a second, more reactive wellbore fluid configured to react with the expandable non-elastomeric material of the clamshell packer, wherein the second wellbore fluid is a brine, and the expansion of the clamshell packer is in induced in presence of the second wellbore fluid.

Implementation 17: The method of any one or more of Implementations 15-16, further comprising: coating the clamshell packer with one or more layers of coating, wherein the one or more layers of coating are configured to alter a reaction rate of a chemical reaction between the clamshell packer and the first wellbore fluid.

Implementation 18: The method of any one or more of Implementations 15-17, wherein clamping the clamshell packer around the coupling of the tubular comprises clamping the clamshell packer between one or more expandable screens disposed along the tubular.

Implementation 19: The method of any one or more of Implementations 15-18, further comprising: forming a plurality of grooves in a surface of the clamshell packer to increase its surface area, wherein increasing the surface area increases the reaction rate of the chemical reaction between the clamshell packer and the first wellbore fluid.

Implementation 20: The method of any one or more of Implementations 15-19, further comprising: verifying the clamshell packer has expanded via a fiber optic cable configured to pass through an opening in the clamshell packer, wherein the fiber optic cable is configured to detect a temperature of the clamshell packer during the chemical reaction.