Expandable and degradable downhole hydraulic regulating assembly   

The present document is a Continuation in Part claiming priority under 35 U.S.C. §120 to U.S. patent application Ser. No. 12/855,503 filed on Aug. 12, 2010, and entitled “Dissolvable Bridge Plug” which is in turn a Continuation in Part of U.S. patent application Ser. No. 11/427,233, filed on Jun. 28, 2006, and entitled, “Degradable Compositions, Apparatus Comprising Same, and Method of Use”. This \'233 Application also in turn claims priority under 35 U.S.C. §119(e) to U.S. Provisional Patent Application Ser. Nos. 60/771,627 and 60/746,097, filed on Feb. 9, 2006, and May 1, 2006, respectively. The disclosures of each of these Applications are incorporated herein by reference in their entireties. Further, the present document is also a Continuation in Part claiming priority under 35 U.S.C. §120 to U.S. patent application Ser. No. 12/763,280, filed on Apr. 20, 2010, and entitled, “Swellable Downhole Device of Substantially Constant Profile”.

Embodiments described relate to deliverable downhole device assemblies for affecting fluid flow in a well. More specifically, assemblies which are configured to swell in order to divert, restrict, or isolate are detailed. Further, these assemblies are also tailored to degrade in the well over a given period, upon exposure to certain downhole conditions, or both.

Exploring, drilling and completing hydrocarbon and other wells are generally complicated, time consuming and ultimately very expensive endeavors. In recognition of these expenses, added emphasis has been placed on efficiencies associated with well completions and maintenance over the life of the well. Over the years, ever increasing well depths and sophisticated architecture have made reductions in time and effort spent in completions and maintenance operations of even greater focus.

Completions and maintenance operations often involve the utilization of isolation mechanisms such as packers, plugs, and other downhole devices. Such devices may be used to sealably isolate one downhole section of the well from another as an application is run in one of the sections. Indeed, a considerable amount of time and effort may be spent achieving such isolations in advance of running the application, as well as in removing the isolation mechanism following the application. For example, isolations for perforating and fracturing applications may involve a significant amount of time and effort, particularly as increases in well depths and sophisticated architecture are encountered. These applications involve the positioning of an isolation mechanism in the form of a bridge plug. More specifically, the bridge plug is located downhole of a well section to be perforated and fractured. Positioning of the bridge plug may be aided by pumping a driving fluid through the well. This may be particularly helpful where the plug is being advanced through a horizontal section of the well.

Once in place, equipment at the oilfield surface may communicate with the plug over conventional wireline so as to direct setting thereof. In the circumstance of a cased well, such setting may include expanding slips of the plug for interfacing a casing wall of the well and thereby anchoring of the plug in place. A seal of the plug may also be expanded into sealing engagement with the casing. Thus, structural and hydraulic isolation may be achieved.

Once anchored and hydraulically isolated, a perforation application may take place above the plug so as to provide perforations through the casing in the corresponding well section. Similarly, a fracturing application directing fracture fluid through the casing perforations and into the adjacent formation may follow. This process may be repeated, generally starting from the terminal end of the well and moving uphole section by section, until the casing and formation have been configured and treated as desired.

The presence of the set bridge plug as indicated above keeps the high pressure perforating and fracturing applications from affecting well sections below the plug. Indeed, even though the noted applications are likely to generate well over 5,000 psi, the well section below the plug is kept isolated from the section thereabove. This degree of isolation is achieved largely due to the use of durable metal features of the plug, including the above noted slips, as well as a central mandrel.

Unfortunately, unlike setting of the bridge plug, wireline communication is unavailable for releasing the plug. Rather, due to the high pressure nature of the applications and the degree of anchoring and sealing required of the plug, it is generally configured for near permanent placement once set. As a result, removal of a bridge plug may be quite challenging, particularly where the plug is set in a horizontal section of the well as detailed further below.

In many circumstances, a packer or seal such as that of the plug may be of a swellable configuration. That is, rather than employing a more challenging isolation technique, the seal may be of a material configured to swell upon exposure to certain downhole conditions. Generally, the material is configured to expand or ‘swell’ upon exposure to brine. As used herein, the term brine is meant to refer to any water-based fluid containing a measureable concentration of a salt such as sodium chloride. A brine swellable material may be well suited for construction of a seal that is to be exposed to a commonly encountered horizontal terminal end of a well. This is because such locations are often partially open-hole and prone to brine production. However, as alluded to above, due to the likely continued presence of brine in the horizontal section, the seal may be set for long term placement.

As also alluded to above, the slips of the plug may be anchored in a near permanent manner as well. Thus, ultimately a labor and time intensive drill-out of the plug may be required. Indeed, each drill-out of a plug in a horizontal well section may require hours of dedicated manpower and drilling equipment. All in all, this may add up to several days and several hundred thousand dollars in added manpower and equipment expenses, solely dedicated to bridge plug drill-out. Unfortunately, even with such expenses incurred, the most terminal or downhole horizontal plugs are often left in place, with the drill-out application unable to achieve complete plug removal, thus cutting off access to the last several hundred feet of the well. Furthermore, a host of other isolation mechanisms make use of metal based anchoring and support features as well as swellable elastomer based sealing elements, both of which display far greater setting than releasing characteristics.

SUMMARY

A downhole isolation mechanism is disclosed for use in a well. The mechanism includes a metal based component configured for degrading in the well. A seal is also provided that is coupled to the metal based component and configured to swell upon exposure to a downhole condition. Further, the seal is also configured to shrink upon the degrading.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a side, partially-sectional view of an embodiment of an expandable and degradable downhole hydraulic regulating assembly in the form of a bridge plug.

FIG. 2 is an overview of an oilfield accommodating a well with the hydraulic regulating bridge plug of FIG. 1 employed therein.

FIG. 3 is an enlarged view of a downhole area taken from 3-3 of FIG. 2 and revealing seal and slip interfaces of the bridge plug with a casing of the well.

FIG. 4A is the enlarged view of FIG. 3 now revealing the degradable nature of the slip and the changing slip interface as a result.

FIG. 4B is the enlarged view of FIG. 4A now revealing the degradable nature of the seal due to the degrading slip and the changing seal interface as a result.

Referring now to FIG. 5, the overview of FIG. 2 is depicted with the bridge plug of FIG. 1 degraded and displaced eliminating its hydraulic regulating effects.

FIG. 6 is a flow-chart summarizing an embodiment of employing an expandable and degradable hydraulic regulating assembly such as the noted plug.

DETAILED DESCRIPTION

Embodiments are described with reference to certain downhole operations employing an expandable and degradable downhole hydraulic regulating assembly. For example, embodiments herein focus on such an assembly in the form of a bridge plug to aid in perforating and fracturing applications. However, a variety of alternate embodiments of expandable and degradable downhole hydraulic regulating assemblies are possible. For example, any number of devices for more temporary isolations, profilers, diverters, and/or constrictors, may take advantage of expandable and degradable characteristics of embodiments described below. Regardless, embodiments described herein include a downhole assembly of some type that is both expandable for hydraulic regulation and degradable to aid in removal or displacement.

Referring now to FIG. 1, a side, partially-sectional view of an embodiment of an expandable and degradable hydraulic regulating assembly is depicted in the form of a bridge plug 100. The bridge plug 100 is referred to as degradable or dissolvable in the sense that certain features thereof may be configured for passive degradation or dissolution upon exposure to downhole well conditions as detailed further below. As used herein, the term passive degradation is meant to refer to degradation upon exposure to downhole conditions, whether or not such conditions are pre-existing or induced.

In the embodiment of FIG. 1, the plug 100 includes metal based elements of slips 110 and a mandrel 120 which, while ultimately degradable, are initially of substantially high strength and hardness (e.g. L80, P110). Thus, maintaining isolation and anchoring to a casing 380 during a high pressure application may be ensured (see FIG. 3A). In one embodiment, the slips 110 and mandrel 120 are configured to withstand a pressure differential of more than about 8,000 psi to ensure structural integrity of the plug 100. Thus, a standard perforating or fracturing application which induces a pressure differential of about 5,000 psi is not of significant concern.

In spite of the high strength and hardness characteristics of the slips 110 and mandrel 120, their degradable or dissolvable nature allows for subsequent displacement, drill-out or other plug removal techniques to be carried out in an efficient and time-saving manner (see FIG. 5). Incorporating a degradable or dissolvable character into the slips 110 and mandrel 120 may be achieved by use of reactive metal in construction. Namely, as detailed to a greater degree below, the slips 110 and mandrel 120 may be made up of a reactive metal such as aluminum with an alloying element incorporated thereinto. For example, as detailed in U.S. application Ser. Nos. 12/855,503 and 11/427,233, incorporated herein, the alloying element may be elements such as lithium, gallium, indium, zinc and/or bismuth. Thus, over time, particularly in the face of exposure to water, fracturing fluid, high temperatures, and other downhole well conditions, the material of the slips 110 and mandrel 120 may begin to degrade or dissolve.

Continuing with reference to FIG. 1, with added reference to FIG. 2, the plug 100 may also include a seal 150 for isolation upon deployment in a well 280. The seal 150 is swellable. For example, in one embodiment, the seal 150 is of a brine swellable polymeric construction, perhaps of styrenic isoprene block copolymers, polyvinyl alcohol, polylatic acid, or sulfonated polyarylether ketone. Thus, it may be well suited for placement as shown in FIG. 2, where it is exposed to an open hole portion of a lateral leg 285 of the well 280, perhaps prone to brine production. Furthermore, water or brine may be introduced by a well operator to aid in swelling of the seal 150. Thus, the brine swellable construction may help to ensure adequate hydraulic sealing with the well casing 287 at the location of the plug 100.

In one embodiment the seal 150 is constructed of swellable elastomers that are less affected by fluctuations in brine concentration. Thus, its long-term effectiveness may be enhanced. More specifically, polymer particles may be drawn from a betaine group prepared by inverse emulsion polymerization. Additional fillers and vulcanizing agents and other substances may be incorporated into elastomer. Ultimately, the elastomer backbone of the brine swellable material may be tailored with particular concentrations of cations and/or anions grafted thereto so as to reduce the sensitivity thereof to brine concentration. As a result, the seal 150 may be constructed that is swellable in the presence of brine but with a resultant swell profile that is of a reduced sensitivity the actual concentration of brine in the well 180.

The elastomer base material for the seal 150 may also include non-elastomeric polymers and be constructed in a variety of configurations. For example, different non-elastomer and elastomer layers may be individually provided of varying thicknesses. Such layers may be stacked or of interpenetrating networks. Further, the elastomer composition itself may include fillers, plasticizers, accelerants and various fibers. Additionally, non-elastomeric polymer choices may include thermoplastic polymers, such as polyolefins, polyamides, polyesters, thermoplastic polyurethanes and polyurea urethanes, copolymers and blends thereof and/or thermoset polymers such as phenolic and epoxy resins.

Continuing with reference to FIG. 1, the plug 100 is configured for wireline deployment and equipped with a coupling 175 for securing to the wireline. The plug 100 also includes other body portions 160 which may house underlying components and/or serve as structural interfaces between the slips 110, seal 150, head 175 and other plug features. Unlike the slips 110 and mandrel 120, however, none of the body portions 160, the seal 150, or the head 175 is responsible for anchoring or maintaining structural integrity of the plug 100 during a perforating, fracturing or other high pressure applications in the well 280. Thus, at the very outset material choices for these features 150, 160, 175 may be selected based on other operational parameters. For example, the body portions 160 of the plug 100 may be a conventional polymer or fiberglass composite that is selected based on its ease of displacement or drill-out removal following a high pressure application (see FIG. 5).

Referring now to FIG. 2, an overview of an oilfield 200 is depicted which accommodates a well 280 with the bridge plug 100 of FIG. 1 employed therein. More specifically, the bridge plug 100 is employed for isolation above a terminal lateral leg 285 of the well 280. As detailed below, this isolation allows for effective perforating and fracturing applications so as to form a vertical production region 260 of perforations 265 above the plug 100. Nevertheless, follow-on displacement or drill-out of the plug 100 may be efficiently achieved so as to provide access to a lateral production region 270 and perforations 277 located in the lateral leg 285.

In the embodiment shown, a rig 210 is provided at the oilfield surface over a well head 220 with various lines 230, 240 coupled thereto for hydraulic access to the well 280. More specifically, a high pressure line 230 is depicted along with a production line 240. The production line 240 may be provided for recovery of hydrocarbons following completion of the well 280. However, more immediately, this line 240 may be utilized in recovering fracturing fluids. That is, the high pressure line 230 may be coupled to large scale surface equipment including fracturing pumps for generating at least about 5,000 psi for a fracturing application. Thus, fracturing fluid, primarily water, may be driven downhole for stimulation of a production region 260.

In the embodiment of FIG. 2, the well 280, along with production tubing 275, is shown traversing various formation layers 290, 295 and potentially thousands of feet before reaching the noted production region 260. Perforations 265 penetrating the formation 295 may be pre-formed via a conventional fracturing application. Additionally, the production tubing 275 may be secured in place uphole of the region 260 by way of a conventional packer 250. Thus, a high pressure fracturing application as directed through the production tubing 275 may be effectively directed at the region 260.

As to deployment and setting of the bridge plug 100, a variety of techniques may be utilized. For example, as noted above, wireline coupled to the head 175 may be used to drop the plug 100 down the vertical portion of the well 280 (see FIG. 1). The plug 100 may be located at the depicted position, just below the intended location of the vertical production region 260. However, in an alternate embodiment where the region 260 is for locating closer to, or within the lateral leg 285, hydraulic pressure may be employed for directing the plug 100 around the elbow between the vertical and lateral 285 well portions and into position. Regardless, once in place, the slips 110 may be wireline actuated for anchoring as described below. Similarly, the seal 150 may be compressibly actuated for sealing in addition to allowing for swelling as noted above. In other embodiments slickline, jointed pipe, or coiled tubing may be used in deployment of the plug 100. In such embodiments, setting may be actuated hydraulically or though the use of a separate setting tool which acts compressibly upon the plug 100 for radial expansion of the slips 110.

Continuing with reference to FIG. 2, the bridge plug 100 may be deployed as indicated so as to isolate more downhole, portions of the well 280, including the lateral leg 285 and uncased portions thereof. With the bridge plug 100 in place as shown, the fracturing application may be focused at the area of the well 280 between the plug 100 and the packer 250. Thus, high pressure targeting of the perforations 265 of the production region 260 may be achieved. As noted above, subsequent recovery of fracturing fluid may follow through the production tubing 275 and line 240.

Referring now to FIG. 3, an enlarged view of a downhole area taken from 3-3 of FIG. 2 is depicted. In this view, slip 375 and seal 376 interfaces with the casing 287 are readily visible. Indeed, in spite of the anchoring provided by teeth 350 of the slip 110 at the slip interface 375, the seal 150 may be exposed to brine constituents 310 such as sodium chloride (represented by the indicated + symbols). Of course, as detailed above, the makeup of the seal 150 is such that this exposure leads to swelling thereof, thereby enhancing the hydraulic sealing engagement provided by the seal interface 376.

The seal 150 may be of conventional swellable materials. However, as indicated above, in one embodiment, variability in the degree of swell of the seal 150 may be reduced. That is, the seal 150 may be configured to remain of a substantially constant profile. More specifically, upon exposure to brine, the seal 150 may configured to swell to a given degree of between about 50% and 250% over and above its pre-swollen size, limited only by the surrounding structural restriction of the depicted casing 287. In this embodiment, the seal 150 is constructed of materials such that the achieved profile, or given degree to which the seal 150 is swollen, varies by no more than about 30% so long as the brine concentration remains less than about 10%.

In an alternate embodiment, where exposure to water or brine is less likely, the seal 150 may be configured to swell upon exposure to hydrocarbons. For example, in one embodiment, the seal 150 may be of a polyarylether ketone of tailored sulfonation to enhance swell upon hydrocarbon exposure. As such, sealing engagement of the seal 150 and casing 187 at the interface 376 may be adequately ensured. Nevertheless, as with brine swellable embodiments, the seal 150 may still be configured for dissolution upon degradation of other metal based components of the plug 100 as described further below.

Continuing with reference to FIG. 3, with added reference to FIG. 2, the well 280 is defined by conventional casing 287 as noted. In this view, the slip interface 375 reveals the indicated teeth 350 of the slip 110 which dig into the casing 287, thereby anchoring the plug 100 in place. Indeed, in spite of differential pressure potentially exceeding about 5,000 psi during the noted fracturing application, or during the preceding perforating, the slips 110 help keep the plug 100 immobilized as shown. Similarly, with added reference to FIG. 1, the internal mandrel 120 helps to ensure structural integrity of the plug 100 in the face of such high pressures. As noted above, the mandrel 120 may be rated for maintaining structural integrity in the face of an 8,000-10,000 psi or greater pressure differential.

Referring now to FIG. 4A, the enlarged view of FIG. 3 is depicted, now revealing the degradable nature of the slip 110 and the changing slip interface 375 as a result. More specifically, the plug 100 of FIG. 4A is depicted following a degrade period in the well 280. Noticeably, the visible slip 110 has undergone a degree of degradation or dissolve over the degrade period. Indeed, the underlying support structure for the teeth 350 of the slip 110 as shown in FIG. 3 has eroded away. Thus, the teeth 350 are no longer supported at the casing 380. This leaves only an eroded surface 400 at the interface 375. As a result, the plug 100 is no longer anchored by the slips 110 as described above. The internal support structure of the mandrel 120 of FIG. 1 is similarly degraded over the degrade period. As a result, a follow-on displacement or drill-out application may take place over the course of less than about 30 minutes, preferably less than about 15 minutes (see FIG. 5).

The degrade rate of the plug 100 may be tailored by the particular material choices selected for the reactive metals and alloying elements described above. That is, material choices selected in constructing the slips 110 and mandrel 120 of FIG. 1 may be based on the downhole conditions which determine the degrade rate. For example, when employing reactive metals and alloying element combinations as disclosed herein and in the \'233 Application, incorporated herein by reference as detailed above, the higher the downhole temperature and/or water concentration, the faster the degrade rate.

Continuing with reference to FIG. 4A, with added reference to FIG. 1, downhole conditions which affect the degrade rate may be inherent or pre-existing in the well 280. However, such conditions may also be affected or induced by applications run in the well 280 such as the above noted fracturing application. That is, a large amount of fracture fluid, primarily water, is driven into the well 280 at high pressure during the fracturing operation. Thus, while the plug 100 may be exposed to an open-hole portion of the well 280 and a certain degree of brine, a greater degree of exposure to water is now guaranteed.

In circumstances where the well 280 is otherwise relatively water-free or not of particularly high temperature, the duration of the fracturing application may constitute the bulk of downhole conditions which trigger the degrade. Alternatively, the well 280 may already be significantly water producing or of relatively high temperature (e.g. exceeding about 75° C.). In total, the slips 110 and mandrel 120 are constructed of materials selected based on the desired degrade rate in light of downhole conditions whether inherent or induced as in the case of fracturing operations. Further, where the conditions are induced, the expected duration of the induced condition (e.g. fracturing application) may also be accounted for in tailoring the material choices for the slips 110 and mandrel 120.

While material choices may be selected based on induced downhole conditions such as fracturing operations, such operations may also be modulated based on the characteristics of the materials selected. So, for example, where the duration of the fracturing application is to be extended, effective isolation through the plug 100 may similarly be extended through the use of low temperature fracturing fluid (e.g. below about 25° C. upon entry into the well head 220 of FIG. 2). Alternatively, where the fracture and dissolution periods are to be kept at a minimum, a high temperature fracturing fluid may be employed.

Compositions or material choices for the slips 110 and mandrel 120 are detailed at great length in the noted \'233 Application. As described, these may include a reactive metal, which itself may be an alloy with structure of crystalline, amorphous or both. The metal may also be of powder-metallurgy like structure or even a hybrid structure of one or more reactive metals in a woven matrix. Generally, the reactive metal is selected from elements in columns I and II of the Periodic Table and combined with an alloying element. Thus, a high-strength structure may be formed that is nevertheless degradable.

In most cases, the reactive metal is one of calcium, magnesium and aluminum, preferably aluminum. Further, the alloying element is generally one of lithium, gallium, indium, zinc, or bismuth. Also, calcium, magnesium and/or aluminum may serve as the alloying element if not already selected as the reactive metal. For example, a reactive metal of aluminum may be effectively combined with an alloying element of magnesium in forming a slip 110 or mandrel 120.

In other embodiments, the materials selected for construction of the slips 110 and mandrel 120 may be reinforced with ceramic particulates or fibers which may have affect on the rate of degradation. Alternatively, the slips 110 and mandrel 120 may be coated with a variety of compositions which may be metallic, ceramic, or polymeric in nature. Such coatings may be selected so as to affect or delay the onset of degrade. For example, in one embodiment, a coating is selected that is itself configured to degrade only upon the introduction of a high temperature fracturing fluid. Thus, the degrade period for the underlying structure of the slips 110 and mandrel 120 is delayed until fracturing has actually begun.

The particular combinations of reactive metal and alloying elements which may be employed based on the desired degrade rate and downhole conditions are again detailed at great length in the noted \'233 Application. Factors such as melting points of the materials, corrosion potential and/or the degradability in the presence of water, brine or hydrogen may all be accounted for in determining the makeup of the slips 110 and mandrel 120.

In one embodiment, the degrade apparent in FIG. 4A may take place over the course of between about 5 and 10 hours. During such time, a perforating application may be run whereby the perforations 265 are formed. Further, a fracturing application to stimulate recovery from the formation 295 through the perforations 265 may also be run as detailed above. Additionally, to ensure that the plug 100 maintains isolation throughout the fracturing application, the degrade rate may be intentionally tailored such that the effective life of the plug 100 extends substantially beyond the fracturing application. Thus, in one embodiment where hydrocarbon recovery is possible downhole of the plug 100, the plug 100 may be actuated via conventional means to allow flow therethrough. This may typically be the case where the plug 100 is employed in a vertical section of the well 280 as depicted in FIG. 2.

Continuing with reference to FIG. 4A, the degradation of metal based components such as the slip 110, also has the effect of releasing seal shrinking constituents 410. For example, the above described dissolution of the slip 110 is likely to dramatically affect the pH of the vicinity of the plug 100. More specifically, a typical downhole pH may be a bit acidic, say in the 5-6 range. However, dissolution of, for example, an aluminum based slip 110 and other components releases constituents 410 that are likely to drive the local pH up to a level of between about 9 and 11. As described below, such a pH range is likely to shrink the seal 150.

Referring now to FIG. 4B, the enlarged view of FIG. 4A is depicted now revealing the shrinking nature of the seal 150 due to the degrading slip 110. In this view, the changing seal interface 376 with the casing 287 is quite apparent. Indeed, the shrinking of the seal 150 appears to be in the form of an actual degradation of the seal 150 as a result of exposure to the noted seal shrinking constituents 410.

In addition to exposure to the noted constituents 410 other readily available measures may utilized in shrinking/degrading the seal 150. For example, use of hotter fluids, above about 35° C. or so, during the perforating and/or fracturing applications, may increase the rate of dissolution of both the slip 110 and the seal 150. So to, would use of higher pH fluids, say above 7, during such applications. Of course, depending on the nature and duration of such applications, lower pH and temperature fluids may be employed where maintenance of the interfaces 375, 376 is sought for longer durations. In this manner, both the makeup of the seal 150 and slip 110 as well as the protocol of the applications may be tailored to support the duration of the interfaces 375, 376 sought.

Referring now to FIG. 5, the overview of FIG. 2 is depicted with the bridge plug 100 of FIG. 1 now degraded and displaced eliminating its hydraulic regulating effects. That is, once the above interfaces 375, 376 are rendered substantially ineffective for anchoring and sealing as depicted in FIG. 4B, the plug 100 may be displaced, for example, by pushing off to the non-productive terminal end of the well 280 as shown in FIG. 5. This may be achieved through a conventional coiled tubing or perhaps tractor driven application. Alternatively, where a non-productive terminal end of the well 280 is unavailable, a conventional drill-out application may be employed to effect substantial disintegration of the entire bridge plug 100. Regardless, the dissolution of the metal based components such as the slips 110 as well as the seal 150 of FIG. 1 allow for such displacement or drill-out application to take place in a matter of minutes. This, in spite of the once durable structural characteristics of the slips 110 and swollen nature of the seal 150 (see FIGS. 1 and 2).

As depicted in FIG. 5, with the plug 100 out of the way, the production tubing 275 may be extended to traverse both production regions 260, 270. In the embodiment shown, the tubing 275 is terminated at a packer 500 and includes openings 560, 570 adjacent each respective production region 260, 270. Of course additional packers for stabilization as well as a host of other architectural features may be provided to the downhole completion. Whatever the case, features of the hydraulic regulating bridge plug 100 ensure that its displacement or removal contributes a substantially minimal amount to the overall time spent attaining the completion.

Referring now to FIG. 6, a flow-chart summarizing an embodiment of employing an expandable and degradable hydraulic regulating mechanism or assembly such as the noted plug is shown. As indicated at 620, the mechanism is positioned downhole for hydraulic regulation where it may be exposed to brine or hydrocarbons 630, 640. Through such exposure or other means, a component of the mechanism may be swollen as noted at 650. Thus, a hydraulically regulated application may be run as indicated at 660.

Perhaps most notably, is the manner by which the mechanism may be dissolved or degraded for eventual displacement or removal. Namely, as indicated at 670 a metal-based component of the mechanism may be degraded. This may be upon exposure to the application noted at 660, positioning in the downhole environment as noted at 620, or both. Regardless, as indicated at 680, the swollen component may be shrunk by exposure to constituents of the degrading metal-based component.

Embodiments described hereinabove provide an expandable and degradable mechanism for downhole hydraulic regulation. The mechanism, may be used to manage hydraulic flow downhole, as in the case of a bridge plug. The mechanism may include swellable features such as that of a packer or seal as well as durable anchoring and structural features such as slips and mandrels. Nevertheless, long term placement of the mechanism may be avoided without requiring labor and time intensive drill-outs or other substantially expensive measures be taken.

The preceding description has been presented with reference to presently preferred embodiments. Persons skilled in the art and technology to which these embodiments pertain will appreciate that alterations and changes in the described structures and methods of operation may be practiced without meaningfully departing from the principle, and scope of these embodiments. Furthermore, the foregoing description should not be read as pertaining only to the precise structures described and shown in the accompanying drawings, but rather should be read as consistent with and as support for the following claims, which are to have their fullest and fairest scope.