• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    multi-zone fracturing and sand control system and method of completion. the present invention relates to a system of multi-zone fracturing and completion of sand control employable in a drilling hole. the system includes a coating. a fracturing assembly includes a telescopic fracturing unit extendable from the liner to the drilling hole and a mobile fracturing sleeve in the liner to access or lock the telescopic fracturing unit; and, an opening in the liner. the opening includes a dissolvable buffer material capable of maintaining the fracturing pressure in the coating during a fracturing operation through the telescopic unit. Also included is a method of operation on a drilling hole.
    公开号:BR112015007459B1
    申请号:R112015007459-6
    申请日:2013-09-06
    公开日:2021-04-13
    发明作者:Colin P. Andrew；Bradley G. Baker；Michael H. Johnson
    申请人:Baker Hughes Incorporated；
    IPC主号:
    专利说明:

    CROSS REFERENCE TO RELATED REQUESTS
    [001] This application claims the benefit of US Application No. 13/648489, filed on October 10, 2012, which is incorporated into this document by reference in its entirety. BACKGROUND
    [002] In the completion and drilling industry, the formation of drilling holes for the purpose of fluid production or injection is common. Drilling holes are used for the exploration or extraction of natural resources, such as hydrocarbons, oil, gas, water and, alternatively, for the sequestration of CO2.
    [003] To extract natural resources, it is common to cement a coating column in the drilling hole and then drill the column and cement with a drilling gun. The perforations are isolated by the installation and sedimentation of packers or bridge plugs, and then the fracturing fluid is released from the surface to fracture the formation outside the isolated perforations. The drilling hole that has the cemented lining column is known as a coated hole. The use of a drill gun is typically carried out in sequence from the bottom of the coated hole to the surface. The use of drill guns virtually eliminates the possibility of incorporating optical or sensor cables in an intelligent well system ("IWS") because of the risk of damage to these sensitive systems. In addition, once the liner is perforated, the sieves must be put in place to prevent the sand from being produced with the desired extracted fluids. A sieve must be extended in the production pipe and an additional pipe joint as a seal with a sliding sleeve for a flow selector sieve is also included. The incorporation of the sand control system occupies valuable space in an internal diameter of a coating that limits a diameter of a production pipe passed in it. The sieves, while necessary for the control of sand, also have other issues such as heating points and susceptibility to damage during insertions that do not need to be attended to constantly.
    [004] Instead of cement, another common fracturing procedure involves placing external packers that insulate the areas of the coating. Zones are created through the use of sliding gloves. This method of fracturing involves the proper placement of the packer when preparing the column and the delays to allow the packers to swell to isolate the zones. There are also potential uncertainties as to whether all packers have achieved a seal so that pressure developed in the column reliably goes to the intended area with the pressure released to the column on the surface. Proper sand control and the incorporation of a sand sieve are still, necessarily, for subsequent production.
    [005] Any of these operations is typically carried out in several stages, requiring multiple trips in and out of the drilling hole with the working column, which contributes to expensive probe time. The inside diameter of a production pipe affects the amount of production fluids that are produced through it, however, the ability to incorporate larger production pipes is prohibited by the current systems required to fracture a drilling hole formation wall and for subsequent sand-free production.
    [006] Thus, the technique would be related to the improved systems and methods to limit the amount of trips made in a drilling hole, increasing the internal space available for production, protecting the intelligent systems in the drilling hole and, finally, reducing costs and increasing production. BRIEF DESCRIPTION
    [007] A multi-zone fracturing system and decomposition of sand control usable in a drilling hole, the system including a coating; a fracturing assembly that includes a telescopic fracturing unit extendable from the liner to the drilling hole and a mobile fracturing sleeve in the liner to access or lock the telescopic fracturing unit; and, an opening in the coating, the opening including a dissolvable buffer material capable of maintaining the fracturing pressure in the coating during a fracturing operation through the telescopic unit.
    [008] A method of operation on a drilling hole, the method of which includes providing a coating on a drilling hole, the drilling hole having a diameter between approximately 21.6 cm (8.5 inches) and 27, 3 cm (10.75 inches); and, a tubular runs in the liner, the tubular having an outside diameter greater than 4.45 cm (2 7/8 inches).
    [009] A method of operation in a drilling hole, the method of which includes providing a coating on the drilling hole, the coating having an opening that includes a dissolvable buffer material; extending a telescopic fracturing unit from a fracturing assembly from the liner to a drilling hole formation wall; fracturing the formation wall through the telescopic fracturing unit; moving a sleeve on the liner to block the telescopic fracturing unit; running a tubular in the coating; and dissolving the buffer material, where the buffer material is capable of maintaining the fracturing pressure in the coating during a fracturing operation. BRIEF DESCRIPTION OF THE DRAWINGS
    [0010] The following descriptions should not be considered as limiting in any way. With reference to the attached drawings, the same elements are numbered in the same way:
    [0011] FIGURE 1 shows a partial perspective view and a partial cross-sectional view of an exemplary multi-zone fracturing system for a single trip and completion of sand control at a drilling hole;
    [0012] FIGURE 2 shows a cross-sectional view of an exemplary model of a telescopic fracture assembly;
    [0013] FIGURE 3 shows a cross-sectional view of an exemplary model of a telescopic production assembly;
    [0014] FIGURE 4 shows a cross-sectional view of an exemplary model of a telescopic unit for any of the fracturing or production telescopic assemblies of Figures 2 and 3;
    [0015] FIGURE 5 shows a cross-sectional view of an exemplary modality of a porous sieve material in a coating;
    [0016] FIGURE 6 shows a cross-sectional view of an exemplary modality of a dissolvable buffer material;
    [0017] FIGURE 7 shows a cross-sectional view of an exemplary modality of a portion of the completion system of FIGURE 1 in an open hole;
    [0018] FIGURE 8 shows a cross-sectional view of an exemplary embodiment of a portion of the completion system of FIGURE 1 in a coated hole;
    [0019] FIGURE 9 shows a cross-sectional view of an exemplary modality of a portion of the FIGURE 1 completion system in a coated hole and in combination with an exemplary fiber optic sensor arrangement;
    [0020] FIGURE 10 shows a cross-sectional view of an exemplary modality of the completion system of FIGURE 1 in a coated hole; and,
    [0021] FIGURE 11 shows a cross-sectional view of an exemplary model of the completion system of FIGURE 1 in a coated hole and depicts a method of fracturing and production. DETAILED DESCRIPTION
    [0022] A detailed description of one or more modalities of the device and method described is presented in this document by way of example and not limitation, with reference to the Figures.
    [0023] FIGURE 1 shows an overview of an exemplary modality of a multi-zone fracturing system for single travel and completion of sand control 10. System 10 is usable in a drilling hole 12 that is formed from a surface through a formation, exposing a forming wall 14 in the drilling hole 12. In this exemplary embodiment, the drilling hole 12 is 19.0 cm (10% inches) in diameter in order to accommodate a production coating 16 with external diameter ("OD") of 20.0 cm (9 7/8 inches) which has an internal diameter ("ID") of 21.6 cm (8.5 inches). In the exemplary system 10 described in this document, the sheath 16 does not require drilling and, therefore, optical and sensor cables can be included in the same or even on an exterior of the sheath 16, without risk of damage by the drilling guns. In order to fracture the surrounding formation, a fracturing assembly 18 includes openings 20 (shown in FIGURE 2) in the liner 16 that are provided with telescopic fracturing units 22 and an inner sleeve 24, such as a fracturing sleeve, which can be arranged to block the openings 20 following a fracturing operation. An exemplary embodiment of the telescopic fracturing units 22 is shown in more detail in FIGURE 2. Depending on the formation itself, when the formation is fractured, the fractures can grow up and / or down from the location of the fracture. Therefore, production openings 26 (shown in FIGURE 3) are provided both above the hole and below the hole of the fracturing openings 20 to maximize production in each zone. The production openings 26 are not covered by the glove 24 and due to the fact that the production openings 26 have to maintain pressure in the liner 16 to allow the fracturing operation to be carried out effectively, the production openings 26 are filled with a buffering material 28, such as a metallic material, which maintains pressure until at least subsequent fracturing operations and the insertion of a production tubular 30, after which it can be dissolved or corroded. The production openings 26 additionally include a porous material 32 which remains intact even after dissolving the buffer material 28 therein, particularly when the system 10 is used in an open (uncemented) drilling hole 12. In an exemplary embodiment, the production openings 26 also include the telescopic production units 34, as shown in more detail in FIGURE 3. Although the system described herein is usable in an open (uncemented) drilling hole 12, the telescopic units 22, 34 of the fracturing openings 20 and the production openings 26 allow the liner 16 to be cemented into the drilling hole 12 using cement 36 without blocking any of the openings 20, 26 since the telescopic units 22, 34 can extended to the forming wall 14 before the cementing operation. Although previous fracturing systems require crossing tools that suffer from erosion that limits the amount of fractures to two or three before travel, System 10 contains a large drilling hole area in the order of 2 to 4 times the area of fracture. drilling hole of the current crossing tools that minimize erosion through the placement tool that allows essentially 6 to 12 fractures to be placed in a single trip. Using fracture modeling computational flow dynamics, system 10 could potentially be used for a single-trip multiple zone fracturing system in which any number of zones are possible and any number of volumes of fracture shoring material is allowed to cross.
    [0024] As additionally shown in FIGURE 1, the production tube 30, as an intelligent well system ("IWS"), is insertable in the liner 16. The production tube 30 includes isolation devices, hereinafter referred to as packers 38 , on an exterior of the production tubular 30 e, extend an annular space between an exterior of the production tubular 30 and an interior of the liner 16 to isolate the zones from each other. Each zone preferably includes at least one telescopic fracturing unit 22, at least one production opening 26 between a top hole 38 packer in the zone and at least one telescopic fracturing unit 22 and at least one production opening 26 between a bottom bore packer 38 in the zone and at least one telescopic fracturing unit 22. Placing the fracturing openings 20 between the production openings 26 in each zone maximizes production. In part, due to fracturing openings 20 that eliminate the need for internal structures in the liner 16 to accommodate a drill gun and due, in part, to production openings 26 that have sand control that eliminates the need for a pipe. separate sieve, the production tubular 30 inserted in the 21.6 cm (8.5 inch) inner diameter of the liner 16 is a 6.35 cm (5% inch) IWS or approximately 51% of the drilling hole, which is much larger than a standard 4.45 cm (2 7/8 inch) production tubular that is typically used in a 21.6 cm (8.5 inch) drilling hole or approximately only 34% of the drilling hole . The holes of the packers 38 are also enlarged to accommodate the larger production tube 30. The resulting system 10 that makes it possible to use a larger production tube 30 is capable of enormously increasing the number of barrels per day that can be produced through it, as opposed to a system that can only incorporate a smaller production tube. . System 10 may additionally include inductive / wet-coupling (s) coupling (s) to allow electrical coupling and / or hydraulic coupling to occur between the different sections of the completion system 10 in the liner 16.
    [0025] FIGURE 4 shows an exemplary telescopic unit22, 34 for a fracturing assembly 18 and / or production opening 26. The telescopic unit 22, 34 includes any number of nested sections 44, 46, 48. In an exemplary embodiment, the separate sections 44, 46, 48 of the telescopic unit 22, 34 include outer radial detectors 50 that engage with the inner detent engaging members 52 in the outer sections. Other exemplary modalities of features of telescopic units 22, 34 for use in system 10 are described in US Patent No. 7,798,213 to Harvey et al., Which is incorporated herein by reference, in its entirety.
    [0026] As will be described below in relation to FIGURE 7, sliding sleeve 24 to block access to the telescopic fracturing unit 22 is movable using a displacement tool 74. Alternatively, the sliding sleeve 24 can be operable with a ball that rests in a headquarters. The telescopic units 22, 34 shown in Figures 1 to 4 are shown in an extended position against the forming wall 14, although it should be understood that other telescopic units 22, 34 in the same system 10 must be retracted, such as those in the different zones. The telescopic fracturing unit 22 can be initially blocked with a rupture cap or disk so that the internal pressure in the liner 16 results in the telescopic extension between or between sections 44, 46, 48 in each unit 22. The feed ends 60 of the telescopic unit 22 will make contact with the forming wall 14 such that fracturing fluids do not egress into the surrounding annular space 78 between the liner 16 and the forming wall 14 when employed in an open drilling hole 12 instead of in a cemented drilling hole 12. When cemented, telescopic units 22, 34 are extended to contact the forming wall 14 prior to the cementation process to avoid the need for drilling through cement 36. Since all telescopic units of fracturing 22 are extended, the rupture caps / disks on telescopic fracturing units 22 can be removed. This can be done in many ways, but one way is to use plugs that can dissolve, such as aluminum alloy plugs that will dissolve in an introduced fluid. The dissolution of the plug or the removal of the rupture disk in the fracturing assembly 18 must not affect the buffer material 28 of the production opening 26. Other exemplary modalities of telescopic unit features 22, 34 for use in system 10 are described in the Order Published US No. 2010/0263871 by Xu et al and US Patent No. 7,938,188 by Richard et al, both of which are incorporated herein by reference, in their entirety.
    [0027] In at least one open-hole application, production openings 26 include porous material 32 in it to prevent sand, fracture shoring material or other waste from entering the coating 14. The porous material 32 must have sufficient strength to withstand the pressures of fracturing fluids that pass through the coating 16. As shown in FIGURE 5, solid-state reactions between alternating layers of fillets of different materials 64, 66 produce exothermic heat that, either alone or together with an applied pressure , forms a porous matrix that can be used to fill the production openings 26 of the coating 16. The bilayer energy materials are formed from a variety of materials that include, but are not limited to: Ti and B, Zr and B, Hf and B, Ti and C, Zr and C, Hf and C, Ti and Si, Zr and Si, Nb and Si, Ni and Al, Zr and Al and Pd and Al. An exemplary method of producing porous material 68 is described in US Patent No. 7,644,854 to H olmes et al, which is incorporated into the present by reference, in its entirety. Due to the fact that the porous material 68 is formed in the opening of the liner 16 or in the telescopic unit 34, as shown in FIGURE 3, the inner diameter of the liner 16 is not reduced and, equally, an outer diameter of an inner production tube 30 can be increased.
    [0028] In any open hole or coated hole application, the liner 16 must be able to perform as a "threadless tube" with at least a nominal pressure capable of handling the fracture initiation and propagation pressures. If there is any leak, a separate pipe will be required to seal the openings 20, 26 which would inevitably take up space in the inner diameter of the liner 16 and reduce the space available for the production tubular 30. Monitoring equipment can be integrated into the coating 16 and exposed to sieving pressures greater than 25 Kpsi. An exemplary form of pressure monitoring equipment is described by US Patent No. 7,748,459 to Johnson, which is incorporated herein by reference, in its entirety. To plug production openings 26 in a manner capable of withstanding fracture pressure and to prevent leakage, the plug material 28 includes a compact metal powdered nanomatrix, as described in US Patent Application No. 2011/0132143 of Xu et al, incorporated in this document by reference, in its entirety. As shown in FIGURE 6, an exemplary embodiment of the powdered metal compact 200 includes a substantially continuous cellular nanomatrix 216 that has a nanomatrix material 220, a plurality of dispersed particles 214 that includes a core material 218 that includes Mg, Al, Zn or Mn or a combination thereof, dispersed in the cell nanomatrix 216 and a solid state bonding layer that extends throughout the cell nanomatrix 216 between the dispersed particles 214. The resulting powder metal compact 200 is a metallic material with high strength and lightweight that is selectively and controllably disposable or degradable. The fully dense, synthesized powder compact 200 includes lightweight particle cores and core materials that have multiple single-layer and multi-layer nanoscale coatings. The 200 compact has properties of high mechanical strength, such as compression and wear resistance and controlled dissolution in various well bore fluids. As used herein, "cell" is used to indicate that nanomatrix 216 defines a network of generally repeated and interconnected compartments or cells of nanomatrix material 220 that span and also interconnect dispersed particles 214. As used herein, "nanomatrix" is used to describe the size or scale of the matrix, particularly the thickness of the matrix between the adjacent scattered particles 214. The metal cover layers, which are synthesized together to form the nanomatrix 216 are the cover layers themselves with thickness nanoscale. Since nanomatrix 216 in most locations, in addition to the intersection of more than two dispersed particles 214, it generally comprises interdiffusion and bonding of two layers of cover from adjacent powder particles that have a nanoscale thickness, The matrix formed also has a nanoscale thickness (for example, approximately twice the thickness of the cover layer) and is then described as a nanomatrix 216. The compact powder 200 is configured to be selectively and controllably dissolvable in a drilling hole in response to an altered condition in the drilling hole 12. Examples of the altered condition that can be exploited to provide dissolution capacity include a change in the temperature or temperature of the drilling hole fluid, change in pressure, change flow rate, change in pH or change in the chemical composition of the drilling bore fluid or a combination thereof. Because of the high strength and density of the plug material 28 described above, the production openings 26 buffered with the buffer material 28 are able to maintain pressure in the liner 16 when the liner 16 is pressed until fracturing operations are carried out. In the application of the open hole, the plug material 28 subsequently dissolves after the fracturing operations are completed and the production tube 30 runs in the coating 16, leaving the porous material 32 in the production openings 26 to prevent sand and other wastes flow to the liner 16 and the production tubular 30. In the coated application, the buffer material 28 at the lead end 60 of the telescopic production units 34 dissolves, also, after the fracturing operations are completed and the production tube 30 is inserted, leaving the telescopic units 34 free to receive production fluids that flow through them. Gloves 24 cover the fracture openings 20 after the fracturing operations are completed to prevent any sand from entering through the fracture openings 20 and therefore the liner 16 provides the necessary sand control operation without the need for a tubular separate sieve positioned outside the production tubular 30.
    [0029] FIGURE 7 shows the system 10 prior to the common production tubular completion 30 and packer 38. The system 10 is shown positioned in an open drilling hole 12 with the liner 16 attached in relation to the forming wall 14 with at least a pair of open-hole packers 70 to distinguish the confined area between them as a production zone 72. The pictured zone 72 includes at least one fracturing assembly 18 that has at least one telescopic fracturing unit 22. During insertion, the telescopic unit 22 is in a retracted position to prevent damage to it and the fracturing sleeve 24 can be positioned so that the fracture openings 20 are exposed. After being placed in a desired area of the drilling hole 12 to perform a fracturing task, the telescopic unit 22 is extended as shown in FIGURE 7 to move into contact with the forming wall 14. A service column 74 is provided , which is illustrated to include a locator for confirming or correlating the position of the tool with respect to locator nipple 76, a section of smooth tube with deflection and a fracturing sleeve displacement tool for moving the fracturing sleeve 24 to lock the openings 20 of the telescopic fracturing units 22 when the fracturing operation is completed. In this exemplary embodiment, due to the fact that the liner 16 is not cemented, but instead an annular space 78 is provided for the inlet flow of production fluids, the liner 16 includes production openings 26 provided with the material of buffering described above 28 in an interior of the liner 16 to maintain the fracturing pressure. Porous material 32 is also provided in production openings 26 to filter production fluids entering an interior of liner 16. After the fracturing operation is completed and the IWS / packer column (production tubular 30 and packer 38 ) be inserted, the buffer material 28 is dissolved from the production openings 26 and the porous material 32 remains intact for sand control as the production fluids enter an interior of the liner 16 towards the production tubular 30. Using the system 10 shown in FIGURE 7, a drill hole size of 10.16 cm (8% inches) is capable of allowing an IWS size of 3.81 cm (3% inches) through a Coating ID of 15.24 cm (6 inches) or approximately 41% of drill hole 12. Also, a drill hole size of 19.0 cm (10% inches) is capable of allowing an IWS size of 6 , 35 cm (5% inches) through a 20.32 cm (8 cm) coating ID inches) or approximately 51% of the drilling hole 12.
    [0030] FIGURE 8 also shows system 10 prior to completion with an IWS / packer column 30, 38. System 10 in FIGURE 8, however, is shown positioned in a coated drilling hole 12 with the coating 16 attached to in relation to the forming wall 14 with cement 36. The pictured area 72 includes at least one fracture assembly 18 that has at least one telescopic fracturing unit 22. Due to the cement 36 that fills the annular space 78 between the coating 16 and the wall Forming 14, the production openings 26 must also include telescopic units 34. The buffer material 28 of the production openings 26 is placed at a lead end 60 (a forming wall contact end) of the telescopic production units 34 to force the telescopic production units 34 to their extended position by means of internal pressure. During insertion, the telescopic units 22, 34 of both the fracture assembly 18 and the production opening 26 are in their retracted positions to prevent damage to them. After being placed in a desired area of the drilling hole 12 to perform a fracturing task, the telescopic unit 22 of the fracturing assembly, as well as the telescopic unit 34 of the production opening 26 are extended as shown to move into contact with the forming wall 14. The annular space 78 can then be cemented. As in the application of open drilling hole 12, service column 74 is provided. After the fracturing operation is completed and the IWS / packer column 30, 38 is inserted, the buffer material 28 in the production opening 26 is dissolved. If the sieve material 32 is supplied as shown in FIGURE 3, it will remain intact for sand control as the production fluids enter an interior of the liner 16 towards the production tubular 30. Using system 10 shown in FIGURE 8, a 10.16 cm (8 ^ inch) drill hole size is capable of allowing a 5.08 cm (4 ^ inch) IWS size through a 7.62 cm casing ID (6 ^ inches) or approximately 53% of the drill hole 12. Also, a 19.0 cm (10% inch) drill hole size is capable of allowing an IWS size of 6.35 cm (5 ^ inches) ) through a 20.32 cm (8 inch) casing ID or approximately 51% of the drilling hole 12.
    [0031] FIGURE 9 shows another exemplary modality of a coated application of the fracturing and sand control system 10. This modality is similar to that shown in FIGURE 8, but additionally includes a fiber optic sensor arrangement cable 86 of detection of distributed temperature ("DTS") on an exterior of the liner 16. It is important to note that such an arrangement would not be feasible if the cemented liner 16 was drilled using a drill gun. Although a DTS 86 cable is shown, it will be understood that smart, fiber optic and / or electrical cables and / or alternate systems can also be placed on or in connection with the sheath 16, which would otherwise be damaged during a drilling process.
    [0032] FIGURE 10 shows the system 10 of FIGURE 8 with a production tube 30 inserted in it. The illustrated IWS / packer column 30, 38 regulates production with an interior and isolated valve in a pictured zone 72 that uses packers 38. The IWS 30 can include additional sand control redundancy with the use of the porous sieve material 32 described above placed on ports 88 of IWS 30.
    [0033] A method of employing the system 10 shown in FIGURE 10 is described with reference to FIGURE 11. The casing 16 of the system 10 runs through a drilling hole 12 with a service column 74 (shown in Figures 7 to 9) at the end bottom or well below. By deflecting the service column 74, the pad is leveled to release the drilling hole 12. The liner 16 is pressed to extend the telescopic units 22, 34 of the fracturing assembly 18 and the production openings 26. The annular space 78 between the liner 16 and the forming wall 14 is then cemented. The liner hanger packers are adjusted. Then, the profile / seal hole is located and seated with weight. The illustrated region 72 is fractured by breaking a disk / plug in the telescopic unit 22 of the fracturing assembly 18 and by passing through the fracturing fluid which includes a washing procedure performed on the fractures. The profile of the fracturing sleeve 24 is engaged by the displacement tool and moved to a closed position to cover the fracture openings 20. The service column 74 is pulled into the next zone. When the zones have been fractured, an internal completion column (production tube 30) flows through the liner 16. The buffer material 28 is dissolved and the production fluids are produced through the production openings 26 and to the doors 88 of the tubular production 30.
    [0034] Thus, a new approach to complete multi-zone fracturing sand control has been described, which vastly increases the amount of production by enabling the use of 30 larger production tubulars in standard size coatings 16 A larger area for the stimulation spine is also provided without limiting issues of erosion or pumping rate for single-zone multi-zone stimulation. Perforation is eliminated in coated hole applications and issues with migration of drilling fines are then eliminated. External DTS applications are permitted in coated and cemented well holes. Sand control is also guaranteed. Overall, well performance is improved while reducing costs and expanding IWS options.
    [0035] Although the invention has been described with reference to the exemplary modality or modalities, it will be understood by those skilled in the art that various changes can be made and the equivalents can be substituted for the elements thereof without departing from the scope of the invention. In addition, many modifications can be made to adapt a particular situation or material to the teachings of in without departing from its essential scope. Therefore, it is intended that the invention is not limited to the particular modality disclosed as the best method contemplated for carrying out this invention, but that the invention will include all modalities that fall within the scope of the claims. also, in the drawings and in the description, exemplary modalities of the invention have been revealed and although the specific terms may have been used, they are, unless otherwise stated, used in a generic and descriptive sense only and not for limitation purposes, and the scope of the invention is therefore not limited. Furthermore, the use of the terms first, second, etc. it does not denote any order or importance, but instead the terms first, second, etc. are used to distinguish one element from another. In addition, the use of the terms one, one, etc. it does not denote a quantity limitation, but instead denotes the presence of at least one of the items referred to.
    权利要求:
    Claims (18)
    [0001]
    1. Multi-zone fracturing and sand control completion system (10) usable in a drilling hole (12), characterized by the fact that the system (10) comprises: a coating (16); a fracture assembly (18) which includes an extendable telescopic fracturing unit (22) from the liner (16) to the drilling hole (12) and a mobile fracturing sleeve (24) in the liner (16) to access the telescopic fracturing unit (22 ) during the fracturing operation and to lock the telescopic fracturing unit (22) after the fracturing operation is complete; and, an opening (26) in the coating (16), the opening (26) including a porous material (32) and a dissolvable buffer material (28) capable of maintaining the fracturing pressure in the coating (16) during a fracturing operation through the telescopic unit (34), and the porous material (32) includes at least two different materials fused together by exothermic heat that results from solid state reactions between alternating layers of at least two materials.
    [0002]
    2. System (10), according to claim 1, characterized by the fact that it additionally comprises a tubular (30) inserted in the coating (16), in which an outer diameter of the tubular (30) is greater than 35% of an internal diameter of the drilling hole (12).
    [0003]
    3. System (10) according to claim 1, characterized by the fact that the plugging material (28) in the opening (26) is capable of supporting at least 68.95 MPa (10,000 psi).
    [0004]
    4. System (10), according to claim 1, characterized by the fact that the buffering material (28) is a compact metal powder of nanomatrix.
    [0005]
    5. System (10) according to claim 1, characterized in that the opening (26) additionally includes an extendable telescopic unit (34) from the casing (16) to the drilling hole (12) and the plugging material (28) is positioned at a contact end (60) of the drilling hole (12) of the telescopic unit (34) of the opening (26).
    [0006]
    6. System (10), according to claim 5, characterized by the fact that it additionally comprises cement positioned in an annular space (78) between the coating (16) and a drilling hole wall (14), the telescopic fracturing unit (22) and the telescopic opening unit (34) extended to the drilling hole wall (14) before a cementation procedure.
    [0007]
    7. System (10) according to claim 1, characterized by the fact that the opening (20) in the cladding (16) includes at least one opening (20) positioned above the telescopic fracturing unit (22) and at least at least one opening (20) positioned hole below the telescopic fracturing unit (22, 34) in the same zone of the system.
    [0008]
    System (10) according to claim 7, characterized in that it additionally comprises, in the coating (16), a first packer (38) hole above the telescopic fracturing unit (22) and a second packer (38 ) hole below the telescopic fracturing unit (22) to separate one zone of the system from the other zones in the system.
    [0009]
    9. System (10) according to claim 1, characterized by the fact that it additionally comprises a fiber optic or sensor cable (86) positioned in the sheath (16).
    [0010]
    10. Multi-zone fracturing and sand control completion system (10) usable in a drilling hole (12), characterized by the fact that the system (10) comprises: a coating (16); a fracture assembly (18) which includes an extendable telescopic fracturing unit (34) from the liner (16) to the drilling hole (12) and a mobile fracturing sleeve (24) in the liner (16) to access the telescopic fracturing unit (22 ) during the fracturing operation and to lock the telescopic fracturing unit (22) after the fracturing operation is complete; and, an opening (26) in the liner (16), the opening (26) including a dissolvable buffer material (28) capable of maintaining the fracturing pressure in the liner (16) during a fracturing operation through the telescopic unit (34), a tubular (30) inserted in the liner (16), in which the ports in the tubular (30) additionally include a porous material (32) from at least two different materials fused together by exothermic heat resulting from the reactions in state solid between alternating layers of at least two different materials.
    [0011]
    11. Method of operation in a drilling hole (12) using the system (10) as defined in claim 1, the method being characterized by the fact that it comprises: providing a coating (16) in a drilling hole (12 ), with the drilling hole (12) having a diameter between approximately 21.6 cm (8.5 inches) and 27.3 cm (10.75 inches); and, passing a tubular (30) in the liner (16), the tubular (30) having an outside diameter greater than 4.45 cm (27/8 inches).
    [0012]
    12. Method according to claim 11, characterized in that it additionally comprises, before passing the tubular (30) in the coating (16), fracturing a forming wall (14) through a telescopic fracturing unit (22 ) which extends from the liner (16) to the forming wall (14) while maintaining the fracturing pressure in the liner (16) with a buffer material (28) in an opening (26) in the liner (16).
    [0013]
    13. Method according to claim 12, characterized in that it additionally comprises, before fracturing, extending the telescopic fracturing unit (22) and extending a telescopic non-fracturing unit (34) from the opening (26) in the coating (16) to a formation wall (14) of the drilling hole (12) and cement an annular space between the liner (16) and the formation wall (14).
    [0014]
    Method according to claim 13, characterized in that it further comprises dissolving the buffer material (28), subsequently passing the tubular (30) in the coating (16).
    [0015]
    15. Method of operation in a drilling hole (12) using the system (10) as defined in claim 1, the method being characterized by the fact that it comprises: providing a coating (16) in the drilling hole (12) , extend a telescopic fracture unit (22) from a fracture assembly (18) of the liner (16) to a forming wall (14) of the drilling hole (12); fracture the forming wall (14) through the unit telescopic fracture (22), move a sleeve on the liner (16) to block the telescopic fracturing unit (22), pass a tubular (30) on the liner (16); and dissolving the buffer material (28), where the buffer material (28) is capable of maintaining the fracturing pressure in the liner (16) during a fracturing operation.
    [0016]
    16. Method according to claim 15, characterized in that it further comprises extending a telescopic unit (34) for non-fracturing the opening (26) of the cladding (16) to the forming wall (14) and cementing a space annular between the cladding (16) and the forming wall (14).
    [0017]
    17. Method according to claim 15, characterized in that it additionally comprises providing a porous material (32) in the opening (26) of the coating (16).
    [0018]
    18. Method according to claim 15, characterized in that passing a tubular (30) includes passing a tubular (30) that has an outside diameter greater than 35% of a diameter of the drilling hole (12).
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    同族专利:
    公开号 | 公开日
    BR112015007459A2|2017-07-04|
    GB201507425D0|2015-06-17|
    GB2525324A|2015-10-21|
    AU2013330419A1|2015-04-09|
    US20140096970A1|2014-04-10|
    NO20150361A1|2015-03-24|
    WO2014058548A1|2014-04-17|
    NO342359B1|2018-05-14|
    US9033046B2|2015-05-19|
    AU2013330419B2|2016-10-20|
    GB2525324B|2017-06-14|
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    法律状态:
    2018-11-21| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|
    2020-02-27| B06U| Preliminary requirement: requests with searches performed by other patent offices: procedure suspended [chapter 6.21 patent gazette]|
    2020-11-10| B06A| Notification to applicant to reply to the report for non-patentability or inadequacy of the application [chapter 6.1 patent gazette]|
    2021-02-02| B09A| Decision: intention to grant|
    2021-04-13| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 06/09/2013, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US13/648,489|US9033046B2|2012-10-10|2012-10-10|Multi-zone fracturing and sand control completion system and method thereof|
    US13/648,489|2012-10-10|
    PCT/US2013/058437|WO2014058548A1|2012-10-10|2013-09-06|Multi-zone fracturing and sand control completion system and method thereof|
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