Systems and methods for filling pits.

Abstract

A plugging system for plugging a cased well in a single trip downhole. The plugging system may include a tool string positionable within the cased well and including a bore and a downhole tool coupled to the tool string. The downhole tool may include a first perforating gun, an upper resettable packer, a lower resettable packer, and a flow-through assembly. The first perforating gun may be operable to perforate the casing of the cased well. When the downhole tool is positioned in the cased well, the upper resettable packer may be uphole of the first perforating gun. When the downhole tool is positioned in the cased well, the lower resettable packer may be downhole of the first perforating gun. The flow-through assembly may be positioned between the upper resettable packer and the lower resettable packer and operable to flow fluids into a bore of the cased well.

Description

Systems and Methods for Plugging a WellBACKGROUND

[0001] After an oil or gas well is drilled, it may become desirable to abandon the well if production is no longer possible or economical. It is common practice to plug the well before abandonment to close zones and prevent migration of hydrocarbon fluids. Plugging may be achieved by injecting a settable substance, such as cement, into the well. For example, a well wall sometimes have production perforations in production tubing and / or casing of the well, through which hydrocarbons enter from the surrounding formations and travel to the surface.

[0002] Pulling production tubing and casing out of the well during abandonment is often expensive due to rig use or may not be possible due to rig unavailability. Some plug and abandonment operations leave casing in place by sealing production perforations with cement to form a flow barrier to prevent influx into the casing and flow uphole, including through any tubing present. In other examples, the casing can be perforated at a specific location before placing a cement plug across the annulus and casing.

[0003] However, even when casing is left in place, plugging and abandonment operations typically require multiple downhole tools and, thus, multiple trips downhole to the desired location. Additionally, when conducted offshore, a drilling rig is needed to perform many of the plugging and abandonment operations. Accordingly, such operations are often time-consuming and costly.BRIEF DESCRIPTION OF THE DRAWINGS

[0004] Embodiments of the systems for plugging a well are described with reference to the following figures. The same numbers are used throughout the figures to reference like features and components. The features depicted in the figures are not necessarily shown to scale. Certain features of the embodiments may be shown exaggerated in scale or in somewhat schematic form, and some details of elements may not be shown in the interest of clarity and conciseness.

[0005] FIG. 1 is a schematic view of a plugging system, according to one or more embodiments;

[0006] FIG, 2 is a schematic view of a downhole tool, according to one or more embodiments;

[0007] FIG. 3 is a schematic view of the downhole tool of FIG. 2 positioned in a cased well;

[0008] FIG. 4 is a schematic view of the downhole tool of FIG. 3 at a second location in the cased well; and

[0009] FIG. 5 is a schematic view of a downhole tool in a cased well, according to one or more embodiments.DETAILED DESCRIPTION

[0010] The present disclosure provides systems for plugging a well. The system al lows for a well to be plugged in a single trip of a downhole tool. The elimination of multipl e trips downhole with different tools allows for a reduction in time and cost for plugging the well. Further, the system can be deployed without the use of a rig, further reducing the costs involved with plugging a well.

[0011] A subterranean formation containing oil or gas hydrocarbons may be referred to as a reservoir, in which a reservoir may be located on-shore or off-shore. Reservoirs are typically located in the range of a few hundred feet (shallow reservoirs) to tens of thousands of feet (ultra-deep reservoirs). To produce oil, gas, or other fluids from the reservoir, a well is drilled into a reservoir or adjacent to a reservoir.

[0012] A well can include, without limitation, an oil, gas, or water production well, or an injection well. As used herein, a “well” includes at least one borehole having a borehole wall. A borehole can include vertical, inclined, and horizontal portions, and it can be straight, curved, or branched. As used herein, the term '‘borehole” includes any cased, and any uncased, open-hole portion of the borehole. Further, the term “uphole” refers a direction that is towards the surface of the well, while the term “downhole” refers a direction that is away from the surface of the well.

[0013] FIG. 1 is a plugging system 100, according to one or more embodiments. The exemplary plugging system 100 is utilized to create a cement plug within a cased borehole 102 extending through various earth strata in an oil and gas formation 104 located below the earth's surface 106. The borehole 102 may be formed of a single or multiple bores extending into the formation 104, and disposed in any orientation. Once set, the cement plug seals the borehole to prevent formation fluids from reaching the surface once production of hydrocarbons from the well has ceased.

[0014] The plugging system 100 utilizes a tool string, such as a coiled tubing system 108, as described in more detail below, to conduct various drilling, production, and well intervention operations. The coiled tubing system 108 is stored on one or more reels 110 positioned near a wellhead 112, A tube guide 114 guides the coiled tubing of the coiled tubing system 108 into an injector 116 supported on a frame assembly 118 and positioned above the wellhead 112, The tube guide 114 is used to feed and direct the coiled tubing of the coiled tubing system 108 into and out of the borehole 102. The injector 116 and the frame assembly 118 may be suspended by a conventional derrick (not shown), a support frame (not shown), or a crane 120; however, none of these structures are required when utilizing the plugging system 100.

[0015] The coiled tubing of the coiled tubing system 108 extends through a blowout preventer (BOP) stack 122 connected to the wellhead 112 for pressure control of the borehole 102. The BOP stack 122 may include one or more BOPs. In some applications, such as, but not limited to wells having equalized pressure within the well or low bottom hole reservoir pressure, with the BOP stack 122 may be omitted. Positioned atop the BOP stack 122 is a lubricator mechanism or one or more stuffing boxes 124, which provides the primary operational seal about the outer diameter of the coiled tubing of the coiled tubing system 108 for the retention of any pressure that may be present at or near the surface of the borehole 102. Although a land-based plugging system 100 is depicted in FIG. 1. the coiled tubing system 108 can be deployed from floating rigs, jackups, platforms, subsea wellheads, or any other well location,

[0016] A working or service fluid source 126. such as a storage tank or vessel, supplies a working fluid to the coiled tubing system 108. In particular, the fluid source 126 is influid communication with a fluid swivel 128 secured to reel 110 and in fluid communication with the interior of coiled tubing system 108. The fluid source 126 may supply any fluid utilized in well operations including, without limitation, cement slurry, drilling fluid, acidizing fluid, liquid water, steam, nitrogen, or some other type of fluid.

[0017] The fluid source 126 may be in fluid communication with a pumping system (not shown) that pressurizes the working fluid at a select pressure, such as during high pressure pumping operation. The fluid source 126 may likewise be in communication with other surface equipment, such as mixers, blenders and the like, utilized to prepare fluids for pumping downhole via the fluid source 126. The fluid source 126 and / or surface equipment may be adjustable in real time responsive to communications during various well operations.

[0018] The plugging system 100 may also include a power supply 130 and a communications huh 132 for sending signals and / or power and otherwise controlling the well operations via electric and / or optic cable deployed within the coiled tubing system 108.

[0019] The well includes one or more casing strings 134 that are cemented in borehole 102, such as the surface, intermediate and production casings 134. An annulus 136 is formed between the walls of sets of adjacent tubular components, such as concentric casing strings 134 or the exterior of the coiled tubing system 108 and the inside wall 138 of borehole 102 or the casing string 134, as the case may be. As shown in FIG. 1, a downhole tool 140 is suspended from the coiled tubing system 108 to plug the well. The downhole tool 140 may be sized to pass through the BOP stack as it is lowered downhole. Alternatively, the BOP stack may not be present and the coiled tubing may include a wellhead connector that engages with the wellhead 112 as the downhole tools is lowered downhole.

[0020] Turning now to FIG. 2, FIG. 2 is a schematic view of a downhole tool 200, according to one or more embodiments. As described above, the downhole tool 200 is lowered into a cased borehole via a tool string that includes coiled tubing, piping, or other similar means to create a cement plug to seal the borehole. The downhole toolincludes upper and lower resettable packers 202, 204 and a perforating gun 206 positioned between the isolation packers.

[0021] The perforating gun 206 of the downhole tool 200 includes at least two sets of charges that, when detonated via a signal from the surface, perforate the casing surrounding the downhole tool 200. As described in more detail below, the two sets of charges within the perforating gun 206 may be detonated at different tunes to perforate a easing in different locations using a single perforating gun 206.

[0022] The downhole tool further includes a flow-through assembly 208. The flow- through assembly 208 is in fluid communication with pumping equipment on the surface via the coiled tubing or piping that positions the downhole tool 200 within the borehole. The flow-through assembly 208 includes a crossover or similar device that is operable to open and close a flowpath between the downhole tool 200 and the cased borehole. The flow-through assembly 208, when opened, allows cement to be pumped downhole, through the downhole tool 200, and into a cased borehole via the downhole tool 200. Accordingly, the flow-through assembly 208 allows a single downhole tool 200 to be utilized in both perforating the casing of the borehole and creating the cement plug within the borehole. Therefore, the time involved with creating the cement plug is decreased when compared to traditional plugging operations that require multiple downhole tools to be positioned downhole at different times.

[0023] The downhole tool 200 also includes a detachable isolation packer 210 on the downhole end of the downhole tool 200. Once the desired location within the borehole is reached, the detachable isolation packer 210 is set within the borehole and released from the downhole tool. As described in more detail below, the detachable isolation packer 210 acts as a lower fluid barrier during the plugging process.

[0024] Turning now to FIG. 3, FIG. 3 is a schematic view of the downhole tool 200 of FIG. 2 positioned in a cased well 300. As described above, the downhole tool 200 is positioned within the cased well 300 via coiled tubing, which includes a wellhead connector 302 that engages with a wellhead, such as the wellhead 112 of FIG. 1. In applications where there is equalized pressure or low bottom hole reservoir pressure, the wellhead connector 302 may be omitted.

[0025] In operation, the downhole tool 200 is lowered into position within the cased well and the detachable isolation packer 210 is set within the cased well 300 to act as a fluid barrier. Alternatively, the detachable isolation packer 210 may be omitted because a fluid barrier is already present or the bottom of the cased well 300 acts as the fluid barrier. Once the detachable isolation packer 210 is set and released, the downhole tool 200 is raised uphole into a first perforation location 304.

[0026] Once the first perforation location 304 is reached, the upper resettable packer 202 is set within the cased well 300 to center the downhole tool 200 and stabilize the downhole tool 200 during the perforation process. Specifically, an electronic signal or pressurized hydraulic fluid is sent downhole to set the isolation packers 202 once the downhole tool 200 reaches the desired location within the borehole. After the upper resettable packer 202 is set, the first set of charges within the perforating gun 206 are detonated to perforate the casing at the first perforation location 304.

[0027] After detonating the first set of charges, the upper resettable packer 202 is retracted and the downhole tool 200 is raised uphole to a second perforation location 400, as shown in FIG. 4. Once the second perforation location 400 is reached, both the upper and lower resettable packers 202, 204 are set with the cased well 300.

[0028] After the upper and lower resettable packers 202, 204 are set within the cased well 300, the second set of charges in the perforation gun are detonated to perforate the casing at the second perforation location 400. Cement is then pumped downhole through the coiled tubing string, out of the flow-through assembly 208, and into the borehole.

[0029] As shown in FIG. 4, once the cement is pumped downhole, a circulation path 402 is established through the perforations at the perforation locations 304, 404 to form the cement plug in the cased well. After a sufficient volume of cement is pumped downhole to form the plug, the upper and lower packers are retracted and the downhole tool 200 is moved uphole and / or withdrawn from the cased well. After the cement is set, it is pressure tested and may then be used as a lownr fluid barrier for further cement plugs to be installed within the well via the downhole tool 200 and methods described above. In one or more embodiments, the downhole 200 conducts the pressure test. Thedownhole tool may be secured in position during the pressure test via the wellhead or remotely operated casing slips that anchor the downhole tool within the cased well 300.

[0030] Turning now to FIG. 5, FIG. 5 is a schematic view of a downhole tool 500 in a eased well 300, FIG. 5 includes many features that are similar to the features described above with reference to F!Gs. 3 and 4, Accordingly, such features will not be described again in detail, except as necessary' for the understanding of the downhole tool 500 shown in FIG. 5.

[0031] As shown in FIG. 5, the downhole tool 500 does not include a detachable isolation packer on the downhole end of the tool. Instead, the downhole tool 500 is intended to be used in situations where a lower fluid barrier 502 is already in place. The downhole tool 500 includes a second perforating gun 504 coupled to the downhole end of the downhole tool 500.

[0032] In operation, the downhole tool 500 is lowered to the desired location within the cased well 300 and the upper resettable packer 202 is set within the cased well 300. The charges within the perforating guns 206, 504 are then detonated to perforate the casing at the first perforation location 304 and the second perforation location 404. The lower resettable packer 204 is then set and the cement plug is created as described above.

[0033] Further examples include:

[0034] Example 1 is a plugging system for plugging a cased well in a single trip downhole. The plugging system includes a tool string positionable within the cased well and including a bore and a downhole tool coupled to the tool string. The downhole tool includes a first perforating gun, an upper resettable packer, a lower resettable packer, and a flow-through assembly. The first perforating gun is operable to perforate the casing of the cased well. When the downhole toyl is positioned in the cased well, the upper resettable packer is uphole of the first perforating gun. When the downhole tool is positioned in the cased well, the lower resettable packer is downhole of the first perforating gun. The flow-through assembly is positioned between the upper resettable packer and the lower resettable packer and operable to flow' fluids into a bore of the cased well.

[0035] In Example 2, the embodiments of any preceding paragraph or combination thereof further include wherein the first perforating gun comprises two sets of charges.

[0036] In Example 3, the embodiments of any preceding paragraph or combination thereof further include wherein the downhole tool comprises a second perforating gun that, when the tool string is positioned in the cased well, is downhole of the lower resettable packer.

[0037] In Example 4, the embodiments of any preceding paragraph or combination thereof further include wherein the first perforating gun and the second perforating gun each comprise two sets of perforating charges.

[0038] In Example 5, the embodiments of any preceding paragraph or combination thereof further include wherein the tool string includes coiled tubing.

[0039] In Example 6, the embodiments of any preceding paragraph or combination thereof further include a connector coupled to the tool string and operable to couple to a wellhead of the cased well.

[0040] In Example 7, the embodiments of any preceding paragraph or combination thereof further include wherein the downhole tool further includes a detachable isolation packer that, when the tool string is positioned in the cased well, is downhole of the lower resettable packer.

[0041] In Example 8, the embodiments of any preceding paragraph or combination thereof further include a pumping system operable to pump the cement through the flow-through assembly and into the cased well via the tool string to create a plug.

[0042] Example 9 is method of plugging a cased well in a single downhole trip of a downhole tool. The method includes lowering the downhole tool within a cased well using a tool string. The method also includes setting an upper resettable packer of the downhole tool in the cased well at a location uphole of a first perforation location. The method further includes perforating casing of the cased well at the first perforation location with the downhole tool. The method also includes perforating the casing at a second perforation location via the downhole tool. The method further includes setting a lower resettable packer of the downhole tool in the cased well at a location betweenthe first perforation location and the second perforation location. The method also includes pumping cement through the downhole tool and into an annulus of the cased well via the perforations in the casing at the second location to create a plug.

[0043] In Example 10. the embodiments of any preceding paragraph or combination thereof further include setting a detachable isolation packer at a location downhole of the lower packer prior to perforating the cased well.

[0044] In Example 11, the embodiments of any preceding paragraph or combination thereof further include coupling a connector of the tool string to a wellhead of the cased well.

[0045] In Example 12, the embodiments of any preceding paragraph or combination thereof further include perforating the cased well at the first perforation location further comprises perforating with a first perforating gun of the downhole tool. The method also includes perforating the cased well at the first perforation location further comprises perforating with a second perforating gun of downhole tool.

[0046] In Example 13, the embodiments of any preceding paragraph or combination thereof further include wherein perforating the cased well at the first perforation location further comprises perforating with a first charge of a perforating gun of the downhole tool. Further, perforating the cased well at the second perforation location further comprises perforating with a second charge of the perforating gun.

[0047] In example 14, the embodiments of any preceding paragraph or combination thereof further include unsetting the upper resettable packer. The method also includes moving the downhole tool to the second perforation location. The method further includes resetting the upper resettable packer with the downhole tool at the second perforation location.

[0048] In Example 15, the embodiments of any preceding paragraph or combination thereof further include pressure testing the plug after the cement has set.

[0049] Example 16 is a downhole tool for use in plugging a cased well with a casing in a single trip downhole. The downhole tool includes a first perforating gun, an upper resettable packer, a lower resettable packer, and a flow-through assembly. The firstperforating gun is operable to perforate the casing of the cased well. When the downhole tool is positioned in the cased well, the upper resettable packer is uphole of the first perforating gun. When the downhole tool is positioned m the cased well, the lower resettable packer is downhole of the first perforating gun. The flow-through assembly is positioned between the upper resettable packer and the lower resettable packer and operable to flow fluids into a bore of the eased well.

[0050] In Example 17, the embodiments of any preceding paragraph or combination thereof further include wherein the first perforating gun includes two sets of perforating charges.

[0051] In Example 18, the embodiments of any preceding paragraph or combination thereof further include wherein the downhole tool comprises a second perforating gun that, when the downhole tool is positioned in the cased well, is downhole of the lower resettable packer.[§052] In Example 19, the embodiments of any preceding paragraph or combination thereof further include wherein the first perforating gun and the second perforating gun each include two sets of perforating charges.

[0053] In Example 20, the embodiments of any preceding paragraph or combination thereof further include a detachable isolation packer that, when the downhole tool is positioned in the cased well, is downhole of the lower resettable packer,

[0054] Certain terms are used throughout the description and claims to refer to particular features or components. As one skilled in the art will appreciate, different persons may refer to the same feature or component by different names. This document does not intend to distinguish between components or features that differ in name but not function.

[0055] Reference throughout this specification to “one embodiment,” “an embodiment,” “embodiments,” “some embodiments,” “certain embodiments,” or similar language means that a particular feature, structure, or characteristic described m connector with the embodiment may be included in at least one embodiment of the present disclosure. Thus, these phrases or similar language throughout this specificationmay, but do not necessarily, all refer to the same embodiment.

[0056] The embodiments disclosed should not be interpreted, or otherwise used, as limiting the scope of the disclosure, including the claims. It is to be fully recognized that the different teachings of the embodiments discussed may be employed separately or in any suitable combination to produce desired results. In addition, one skilled in the art will understand that the description has broad application, and the discussion of any embodiment is meant only to be exemplary of that embodiment, and not intended to suggest that the scope of the disclosure, including the claims, is limited to that embodiment.

Claims

DEPCT661. Sealing system for single-trip casing wellhead sealing. The sealing system comprises an in-trip toolstring for placement in the casing wellhead and a drilling and descending tool connected to the toolstring. The descending tool includes a first-stage perforation gun that operates to perforate the casing of the casing wellhead; an upper, repositionable compressor which, when the descending tool is placed in the casing wellhead, serves as the ascent portion of the first-stage perforation gun; and a lower, repositionable compressor which, when the descending tool is placed in the casing wellhead, serves as the ascent portion of the casing wellhead.

1. The casing insertion system consists of a first-stage casing gun and a flow-through collector positioned between the upper and lower repositionable compressors, with the flow-through collector operating to allow fluid to flow into the casing insertion section of the well.

2. The plugging system of claim 1, in which the first-stage casing gun is composed of two charge sets.

3. The plugging system of claim 1, in which the well insertion system is composed of a second-stage casing gun, which, when the toolstring is placed in the casing insertion section, is the lower repositionable compressor positioned in the well. 4.The sealing system of claim 3, in which each first and second wall perforating gun consists of two perforating charge sets; 5. The sealing system of claim 1, in which the toolstring consists of a coiled tube; 6. The sealing system of claim 1, which also consists of a connector that is coupled to the toolstring and is operational for connection to the wellhead of the casing well; 7. The sealing system of claim 1, in which the wellhead tool also consists of a removable splitter which, when the toolstring is positioned in the casing well, is the lower part of the repositionable splitter; 8. The sealing system of claim 1, which also consists of an operational pumping system to pump cement through the flow collecting unit and into the casing well through the toolstring to create the seal; 9.The method of sealing a casing well in a single trip tooling wellhead involves the following assembly: inserting the tooling into the casing wellhead using a toolstring; setting the upper part of the tooling into the casing wellhead at the first wall perforation position; perforating the casing at the first wall perforation position with the tooling; perforating the casing at the second wall perforation position through the tooling; setting the lower part of the tooling into the casing wellhead between the first and second wall perforation positions; and pumping cement through the tooling and into the casing wellhead ring through the second wall perforation position to create a seal.

10. The method of Claim 9, which also includes setting a removable split compressor at the lower compressor's downing position before perforating the casing wellhead.

11. The method of Claim 9, which also includes connecting the toolstring coupler to the wellhead of the casing wellhead. 12.

13. The method of Claim 9 in which the casing wall at the first venting location is also comprised of venting with the first charge of the wellbore gun and the casing wall at the first venting location is also comprised of venting with the second charge of the wellbore gun.

14. The method of Claim 9 in which the casing wall at the first venting location is also comprised of venting with the first charge of the wellbore gun and the casing wall at the second venting location is also comprised of venting with the second charge of the wellbore gun.

15. The method of Claim 9 in which it is also comprised of removing the repositionable upper compression device, moving the wellbore tool to the second venting location, and repositioning the repositionable upper compression device to the wellbore tool at the second venting location.

16. The method of Claim 9 in which it is also comprised of pressure testing of the seal after cement hardening.

17. The wellhead tool for use in filling casing wells with a single-trip casing section, in which the wellhead tool comprises a first-trip perforating gun that is operational for perforating the casing of the casing well, an upper repositionable compressor which, when the wellhead tool is positioned in the casing well, is the ascent portion of the first-trip perforating gun, a lower repositionable compressor which, when the wellhead tool is positioned in the casing well, is the descent portion of the first-trip perforating gun, and a flow collector which is positioned between the upper and lower repositionable compressors, which is operational to allow fluid to flow into the bore section of the casing well.

18. The wellhead tool of claim 16 in which the first-trip perforating gun comprises two perforating charge units.

19. The wellhead tool of claim 16 in which the wellhead tool comprises a second-trip perforating gun which, when the wellhead tool is positioned in the casing well, is the descent portion of the lower repositionable compressor.The well-driving instrument of claim 18, in which each first and second wall perforating gun consists of two sets of perforating charges;20. The well-driving instrument of claim 16, which also includes a removable splitter which, when the well-driving instrument is placed in the casing well, forms the lower part of the repositionable splitter;