well bore apparatus and methods for zonal isolation and flow control

专利摘要:
HOLE DRILL APPLIANCE AND METHODS FOR ZONAL INSULATION AND FLOW CONTROL. The method for completing a well hole in a subsurface formation includes providing a sand control device representing one or more joints of sand screens, and a plug assembly along the joints with at least one mechanically adjusted plug with at least an alternating flow channel in it. Conducting the shutter assembly and sand screen connected to the well bore, adjusts a mechanically adjusted shutter in engagement with the adjacent well bore, injecting gravel slurry into the well bore to form a gravel packing. An elongated isolation column is conducted in the sand control device by installing a plug with valves that serve as an inflow control device. Then, seals are activated around the insulation column and adjacent to the plug assembly. A zone isolation device allows flow control to be provided above and below the plug assembly.
公开号:BR112013013148B1
申请号:R112013013148-9
申请日:2011-12-06
公开日:2020-07-21
发明作者:Michael T. Hecker；Michael D. Barry；Petrus A.J. Stevens；David A. Howell；Charles S. Yeh；Iain M. Macleod；Lee Mercer；Stephen Reid；Andrew J. Elrick
申请人:Exxonmobil Upstream Research Company；
IPC主号:

专利说明:

[0001] [0001] This application claims the benefit of U.S. Provisional Application No. 61 / 424,427, filed on December 17, 2010; U.S. Provisional Application No. 61 / 482,788, filed May 5, 2011; and U.S. Provisional Application No. 61 / 561,116, filed November 17, 2011. BACKGROUND OF THE INVENTION
[0002] [0002] This section is intended to introduce various aspects of the technique, which can be associated with exemplary embodiments of the present disclosure. This debate is believed to help provide a framework to facilitate a better understanding of particular aspects of this disclosure. Consequently, it should be understood that this section should be read under this understanding, and not necessarily as admissions to the prior art. FIELD OF THE INVENTION
[0003] [0003] The present disclosure refers to the field of well conclusions. More specifically, the present invention relates to the isolation of formations from well holes that have been completed using gravel packaging. The order also relates to a zonal isolation device that can be fitted inside a covered or open hole well hole and incorporates alternate flow channel technology. TECHNOLOGY DEBATE
[0004] [0004] When drilling oil and gas wells, a well bore is formed using a drill bit that is stimulated downstream at a lower end of a drilling column. After drilling to a predetermined depth, the drill column and drill bit are removed and the well hole is coated with a coating column. An annular area is thus formed between the coating column and the formation. A cementation operation is typically conducted in order to fill or “compress” the annular area with cement. The combination of cement and coating reinforces the well bore and facilitates the isolation of the formation behind the coating.
[0005] [0005] It is common to place several columns of coating having progressively smaller external diameters in the well bore. The drilling process and then progressively smaller lining columns are repeated several times until the well has reached full depth. The final coating column, referred to as a production coating, is cemented in place and drilled. In some examples, the final coating column is a sealing coating, that is, a coating column that is not bonded back to the surface.
[0006] [0006] As part of the completion process, a wellhead is installed on the surface. The wellhead controls the flow of production fluids to the surface, or the injection of fluids into the well bore. Fluid accumulation and processing equipment such as tubes, valves and separators are also provided. Production operations can then begin.
[0007] [0007] Sometimes it is desirable to leave the bottom portion of a well hole open. In open-hole conclusions, a production liner is not extended through the production zones and drilled; preferably, the production zones are left uncovered, or "open." A production column or “pipe” is then positioned inside the well bore extending below the last casing column and through a subsurface formation.
[0008] [0008] There are certain advantages to open hole conclusions versus covered hole conclusions. First, because open hole conclusions have no drilling tunnel, formation fluids can converge in the well hole radially 360 degrees. This has the benefit of eliminating the additional pressure drop associated with converging radial flow and then linear flow through particle-filled drilling tunnels. The reduced pressure drop associated with an open hole completion virtually guarantees that it will be more productive than a covered hole, not stimulated in the same formation.
[0009] [0009] Second, open hole techniques are many less expensive stools than covered hole conclusions. For example, the use of gravel packaging eliminates the need for cementing, drilling, and post-drilling cleaning operations.
[0010] [0010] A common problem in open hole conclusions is the immediate exposure of the well hole to the adjacent formation. If the formation is unconsolidated or heavily sandy, the flow of production fluids into the well bore can carry particles from the formation with it, for example, sand and fines. Such particles can be erosive to production equipment at the bottom of the well and to pipes, valves and separation equipment on the surface.
[0011] [0011] To control the invasion of sand and other particles, sand control devices can be used. Sand control devices are usually installed at the bottom of the well through formations to retain solid materials larger than a certain diameter while allowing fluids to be produced. A sand control device typically includes an elongated tubular body, known as a base tube, having numerous grooves or openings. The base tube is then typically wound with a filtering medium such as a winding wire or wire mesh.
[0012] [0012] In order to increase sand control devices, particularly in open hole conclusions, it is common to install a gravel packing. Gravel packing from a well involves placing gravel or other particulate matter around the sand control device after the sand control device is attached or otherwise placed in the well bore. To install a packaging with gravel, particulate material is released at the bottom of the well by means of a carrier fluid. The carrier fluid with the gravel together forms a gravel slurry. The slurry dries in place, leaving a circumferential packing of gravel. The gravel not only helps particle filtration but also helps to maintain the integrity of the formation.
[0013] [0013] In a packaging conclusion with open hole gravel, the gravel is positioned between a sand screen that surrounds a perforated base tube and an adjacent well hole wall. During production, forming fluids flow from the underground formation, through the gravel, through the screen, and into the internal base tube. The base tube thus serves as a part of the production column.
[0014] [0014] A problem historically encountered with gravel packaging is that an inadvertent loss of carrier fluid from the slurry during the release process can result in premature sand or gravel bridges being formed at various locations along open hole intervals. For example, in an interval having high permeability or in an interval that has been fractured, poor gravel distribution can occur due to premature loss of carrier fluid from the gravel slurry in the formation. The premature sand bridge connection can block the flow of gravel slurry, causing voids to form over the completion interval. Similarly, a zonal isolation shutter in the annular space between the screen and the borehole can also block the flow of gravel slurry, causing voids to form over the completion interval. Thus, a complete gravel packing from bottom to top is not obtained, leaving the well hole exposed to the infiltration of sand and fines.
[0015] [0015] The problems of sand bridge connection and deviation zonal isolation were addressed through the use of Alternate Path Technology®. Alternate Path Technology® employs bypass tubes or flow channels that allow gravel slurry to bypass selected areas, for example, premature sand bridges or shutters, along a well hole. Such fluid diversion technology is described, for example, in U.S. Pat. US No. 5,588,487 entitled “Tool for Blocking Axial Flow in Gravel-Packed Well Annulus,” and PCT Publication No. W02008 / 060479 entitled “Wellbore Method and Apparatus for Completion, Production, and Injection,” each of which is incorporated here by reference in its entirety. Additional references that discuss alternating flow channel technology include Pat. No. 8,011,437; Pat. No. 7,971,642; Pat. No. 7,938,184; Pat. No. 7,661,476; Pat. No. 5,113,935; Pat. No. 4,945,991; Publ. of Pat. No. 2010/0032158; Publ. of Pat. No. 2009/0294128; M.T. Hecker, et al., “Extending Openhole GravelPacking Capability: Initial Field Installation of Internal Shunt Alternate Path Technology,” SPE Annual Technical Conference and Exhibition, SPE Document No. 135,102 (September 2010); and M.D. Barry, et al., “Open-hole Gravel Packing with Zonal Isolation,” SPE Document No. 110,460 (November 2007).
[0016] [0016] The effectiveness of a gravel packing in controlling the influx of sand and fines into a well hole is well known. However, it is also sometimes desirable with open-hole conclusions to isolate selected intervals along the open-hole portion of a well hole in order to control the influx of fluids. For example, in relation to the production of condensable hydrocarbons, water can sometimes invade an interval. This may be due to the presence of native water zones, taper (elevation of the hydrocarbon-water contact near the well), streaks of high permeability, natural fractures, or handling of injection wells. Depending on the mechanism or cause of water production, water can be produced at different locations and times during the life of a well. Similarly, a gas hood above an oil reservoir can expand and break, causing production of gas with oil. The rupture of the gas reduces the activation of the gas hood and suppresses oil production.
[0017] [0017] In these and other examples, it is desirable to isolate an interval of production of formation fluids in the well bore. Zonal annular isolation may also be desired for production allocation, production profile / injection fluid control, selective stimulation, or gas control. However, the design and installation of open-hole shutters is highly problematic due to under-enlarged areas, collapsing areas, higher pressure differentials, frequent pressure cycling, and irregular drillhole sizes. In addition, the longevity of zonal insulation is a consideration as the potential for water / gas taper often increases later in the life of a field due to the lowering and suppression of pressure.
[0018] [0018] Therefore, a need exists for an improved sand control system that provides fluid bypass technology for placing gravel that bypasses a shutter. There is still a need for a plug assembly that provides insulation from selected subsurface intervals along a hole in the open hole well. In addition, a need exists for a well bore apparatus that allows for zonal isolation and flow control over gravel packaging within a well bore. SUMMARY OF THE INVENTION
[0019] [0019] A zonal isolating packaging device with gravel for a well hole is first provided here. The zonal isolation apparatus is of particular use in relation to placing a gravel package within an open bore portion of the well bore. The open hole portion extends through one, two, or more subsurface intervals.
[0020] [0020] In one embodiment, the zonal isolation apparatus first includes a pipe column. The tubing column resides within a well bore and is configured to receive fluids. The fluids can be production fluids that have been produced from one or more subsurface intervals. Alternatively, the fluids can be water or other injection fluids being injected into one or more subsurface intervals.
[0021] [0021] The zone isolation device also includes a sand control device. The sand control device includes an elongated base tube. The base tube defines a tubular member having a primary end and a secondary end. The zonal isolation apparatus further comprises a filter means surrounding the base tube along a substantial portion of the base tube. Together, the base tube and the filter medium form a sand screen.
[0022] [0022] The sand screen is arranged to have alternating flow path technology. In this regard, the sand screen includes at least one alternating flow channel to deflect the base tube. The channels extend along the base tube substantially from the primary end to the secondary end.
[0023] [0023] The zone isolation device also includes at least one and, optionally, at least two shutter assemblies. Each shutter assembly includes a mechanically adjusted shutter that serves as a seal. More preferably, each plug assembly has two mechanically adjusted shutters or annular seals. These represent an upper shutter and a lower shutter. Each mechanically adjusted plug has a sealing element that can, for example, be about 6 inches (15.2 cm) to 24 inches (61.0 cm) in length. Each mechanically adjusted plug also has an internal mandrel in fluid communication with the sand screen base tube.
[0024] [0024] Intermediate to at least two mechanically adjusted shutters can optionally be at least one swellable plug element. The swelling plug element is preferably about 3 feet (0.91 meters) to 40 feet (12.2 meters) in length. In one aspect, the swelling plug element is made of an elastomeric material. The intumescent plug element is activated over time in the presence of a fluid such as water, gas, oil, or a chemical. Swelling may occur, for example, should one of the mechanically adjusted shutter elements fail. Alternatively, swelling can occur over time as the fluids in the formation surrounding the swelling plug contact the swelling plug.
[0025] [0025] The swelling element preferably swells in the presence of an aqueous fluid. In one aspect, the swelling plug element may include an elastomeric material that swells in the presence of hydrocarbon liquids or a driving chemical. This can be instead of or in addition to an elastomeric material that swells in the presence of an aqueous fluid.
[0026] [0026] As part of the alternating flow path technology, the zonal isolation apparatus also includes one or more alternating flow channels extending through and along the various elements of the plug within each plug assembly. The alternating flow channels serve to divert the gravel packaging slurry from an upper range to one or more lower intervals during a gravel packaging operation.
[0027] [0027] In one aspect, the first and second mechanically adjusted shutters are uniquely designed to be fitted into the well bore before a gravel packing operation begins. The downhole plug seals an annular region between the mandrel and an adjacent hole in the well. The well hole was preferably completed as an open hole well hole. Alternatively, the well hole can be completed with a covered hole, meaning that a production coating column has been drilled. Alternatively, the well bore can be completed with a blank tube joint, and a mechanically adjusted plug is fitted along the blank tube joint.
[0028] [0028] The zonal insulation device also includes an elongated insulation column. The insulation column comprises a tubular body. The tubular body has an internal diameter defining a hole that is in fluid communication with the pipe column. The tubular body also has an outside diameter configured to reside within the base tube of the screen and the mandrel of the plug assemblies.
[0029] [0029] The zone isolation device also includes a primary valve. The primary valve is placed above or below the plug assembly. The primary valve defines at least one port that can be opened and closed (or any position in the middle) in order to selectively place the hole in the tubular body in fluid communication with a hole in the adjacent base tube.
[0030] [0030] The zone isolation device also includes one or more seals. A seal can be a shutter. The seals reside along the outer diameter of the tubular body. The insulation column is placed so that the seals are adjacent to the plug assembly. When activated, the seals serve to seal an annular region formed between the outer diameter of the tubular body and the adjacent mandrel of an adjusted plug assembly.
[0031] [0031] Preferably, the zone isolation device also includes a secondary valve. In this example, the primary valve or the secondary valve is above the primary plug assembly, and the other of the primary valve and secondary valve is below the primary plug assembly.
[0032] [0032] In one embodiment, the at least one port on the primary valve comprises two or more direct openings through the tubular body, and the secondary valve also comprises two or more direct openings through the tubular body. In this example, the primary valve and the secondary valve can all be configured so that at least one of the two or more direct openings can be selectively closed, thereby partially restricting the flow of fluids through the tubular body. In this way, a true inflow control device is provided.
[0033] [0033] In one embodiment, the zonal isolation device comprises an upper seal and a lower seal. The upper seal and the lower seal are spaced apart along the joints of the base tube in order to span a selected subsurface gap within a well bore. In this embodiment, the isolation column can further comprise a tertiary valve. In this example, the primary valve can be above the primary plug assembly, the secondary valve is intermediate between the primary and secondary plug assemblies, and the tertiary valve is below the secondary plug assembly.
[0034] [0034] A method for completing a well bore in a subsurface formation is also provided here. The well bore preferably includes a bottom portion completed as an open bore. In one aspect, the method includes providing a sand control device. The sand control device complies with the sand control device described above.
[0035] [0035] The method also includes providing a shutter assembly. The shutter assembly is also in accordance with the shutter assembly described above in its various embodiments. The shutter assembly includes at least one, and preferably two, mechanically adjusted shutters. For example, each plug will have an inner mandrel, alternating flow channels around the inner mandrel, and a sealing element external to the inner mandrel.
[0036] [0036] The method also includes connecting the plug assembly to the intermediate sand screen to the two joints of the base tube. The method then includes conducting the shutter assembly and the sand screen connected to the well bore. The plug and the connected sand screen are placed along the open hole portion (or other production interval) of the well hole.
[0037] [0037] The method also includes adjusting at least one mechanically adjusted shutter. This is done by activating the sealing element of the plug in engagement with the open hole portion adjacent to the well hole. Then, the method includes injecting a gravel slurry into an annular region formed between the sand screen and the adjacent open hole portion of the well hole, and then further injecting the gravel slurry through the alternating flow channels to allow that the gravel slurry deviates from the shutter. In this way, the open hole portion of the well hole is packed with gravel above and below the plug after the plug has been fitted to the well hole.
[0038] [0038] In the method, it is preferred that the plug assembly also includes a mechanically adjusted secondary plug. The secondary mechanically adjusted shutter is built according to the primary mechanically adjusted shutter, or is an identical image of it. An intumescible plug afterwards can be optionally supplied intermediate to the primary and secondary mechanically adjusted shutters. The swelling plug has alternating flow channels aligned with the alternating flow channels of the primary and secondary mechanically adjusted shutters. Alternatively, the plug assembly may include a zonal isolation tool based on gravel intermediate the primary and secondary shutters.
[0039] [0039] The method also includes driving a pipe column into the well bore with an elongated insulation column connected to a lower end of the pipe column. The insulation column comprises: a tubular body having an internal diameter defining a hole in fluid communication with a hole in the pipe column, and an external diameter configured to reside within the base tube of the sand control device and within the internal mandrel of the plug assembly, a primary valve, and one or more seals along the outer diameter of the tubular body.
[0040] [0040] The method then includes placing the elongated insulation column inside the base tube and through the plug assembly. In this way, the primary valve of the isolation column is above or below the plug assembly, and the seals of the insulation column are adjacent to the adjusted plug assembly.
[0041] [0041] The method also includes activating the seals in order to seal an annular region formed between the outer diameter of the tubular body and the mandrel adjacent to the adjusted plug assembly.
[0042] [0042] It is preferred that the primary valve comprises two or more direct openings through the tubular body. In this example, the method further includes closing at least one of the two or more direct openings, thereby partially restricting the flow of fluids through the tubular body. It is also preferred that the isolation column includes a secondary valve. In this example, the primary valve or the secondary valve is above the plug, and the other from the primary valve and the secondary valve is below the plug. In this example, the method further includes closing the primary valve, the secondary valve, or both, or alternatively opening the primary valve, the secondary valve, or both, thereby creating fluid communication between the selected valve and a bore in the base.
[0043] [0043] The method may also include producing hydrocarbon fluids from at least one gap along the open bore portion of the well bore. Alternatively, the method may also include injecting fluids in at least one interval along the open bore portion of the well bore. BRIEF DESCRIPTION OF THE DRAWINGS
[0044] [0044] So that the way in which the present inventions can be better understood, certain illustrations, graphs and / or flowcharts are attached to this one. It should be noted, however, that the drawings illustrate only selected embodiments of the inventions and therefore should not be considered limiting in scope, so that the inventions can support other equally effective embodiments and applications.
[0045] [0045] Figure 1 is a cross-sectional view of an illustrative well bore. The well hole was drilled through three different subsurface intervals, each interval being below formation pressure and containing fluids.
[0046] [0046] Figure 2 is an enlarged cross-sectional view of an open hole completion of the well hole in Figure 1. The completion of an open hole at the depth of the three illustrative intervals is most clearly seen.
[0047] [0047] Figure 3A is a side view in cross section of a plug assembly, in one embodiment. Here, a base tube is shown, with adjacent plug elements. Two mechanically adjusted shutters are shown, along with an intermediate intumescent shutter element.
[0048] [0048] Figure 3B is a cross-sectional view of the plug assembly of Figure 3A, taken through lines 3B-3B of Figure 3A. Bypass tubes are observed inside the swelling plug element.
[0049] [0049] Figure 3C is a cross-sectional view of the plug assembly of Figure 3A, in an alternate embodiment. Instead of bypass tubes, transport tubes are observed multiplied around the base tube.
[0050] [0050] Figure 4A is a side view in cross section of the plug assembly of Figure 3A.
[0051] [0051] Here, sand control devices, or sand screens, were placed at opposite ends of the shutter assembly. Sand control devices use external bypass tubes.
[0052] [0052] Figure 4B provides a cross-sectional view of the plug assembly of Figure 4A, taken through lines 4B-4B of Figure 4A. Bypass tubes are observed outside the sand screen to provide an alternative flow path for a particulate slurry.
[0053] [0053] Figure 5A is another side view in cross section of the plug assembly of Figure 3A. Here, sand control devices, or sand screens, were again placed at opposite ends of the shutter assembly. However, sand control devices use internal bypass tubes.
[0054] [0054] Figure 5B provides a cross-sectional view of the plug assembly of Figure 5A, taken through lines 5B-5B of Figure 5A. Bypass tubes are observed within the sand screen to provide an alternative flow path for a particulate slurry.
[0055] [0055] Figures 6A to 6N show stages of a gravel packing procedure using one of the shutter assemblies of the present invention, in one embodiment. Alternating flow path channels are provided through the shutter elements of the shutter assembly and through sand control devices.
[0056] [0056] Figure 60 shows the assembly of the plug and packing with gravel having been fitted into a hole in the open borehole following the completion of the packing procedure with gravel of Figures 6A to 6N.
[0057] [0057] Figure 7A is a cross-sectional view of an intermediate interval of the open hole completion of Figure 2. Here, a transposition plug was placed inside a sand control device through the intermediate interval to prevent the inflow of formation fluids.
[0058] [0058] Figure 7B is a cross-sectional view of intermediate and lower intervals of the open hole completion of Figure 2. Here, a plug was placed inside a plug assembly between the intermediate and lower intervals to prevent fluid flow. formation above the well bore from the lower interval.
[0059] [0059] Figure 8 is a schematic side view of a well bore having an isolation column of the present invention, in an embodiment, placed in it.
[0060] [0060] Figure 9A is another cross-sectional view of an intermediate interval of the open hole completion of Figure 2. Here, a zonal insulation column was placed inside a sand control device along the intermediate interval, with the valves closed to prevent the inflow of formation fluids from the intermediate interval.
[0061] [0061] Figure 9B is a cross-sectional view of intermediate and lower intervals of the open hole completion in Figure 2. Here, a zonal insulation column was placed inside a sand control device along the intermediate and lower intervals. , with the valves closed to prevent the flow of formation fluids above the well bore from the lower range.
[0062] [0062] Figure 10 is a flow chart for a method of completing a well bore, in one embodiment. The method involves driving a sand control device and mounting a plug into a well hole, fitting a plug, installing a gravel package into the well hole, and driving a zonal isolation column into the sand control device. DETAILED DESCRIPTION OF CERTAIN WAYS OF ACCOMPLISHMENT Definitions
[0063] [0063] As used here, the term "hydrocarbon" refers to an organic compound that includes mainly, if not exclusively, the elements hydrogen and carbon. Hydrocarbons generally fall into two classes: aliphatic or straight chain hydrocarbons, and cyclic or closed ring hydrocarbons, including cyclic terpenes. Examples of hydrocarbon-containing materials include any form of natural gas, oil, coal, and bitumen that can be used as a fuel or enhanced in a fuel.
[0064] [0064] As used here, the term "hydrocarbon fluids" refers to a hydrocarbon or mixtures of hydrocarbons that are gases or liquids. For example, hydrocarbon fluids can include a hydrocarbon or mixtures of hydrocarbons that are gases or liquids under formation conditions, processing conditions or ambient conditions (15 ° C and pressure at 1 atm). Hydrocarbon fluids can include, for example, oil, natural gas, coal methane, shale oil, pyrolysis oil, pyrolysis gas, a coal pyrolysis product, and other hydrocarbons that are in a gaseous or liquid state .
[0065] [0065] As used here, the term "fluid" refers to gases, liquids, and combinations of gases and liquids, as well as combinations of gases and solids, and combinations of liquids and solids.
[0066] [0066] As used here, the term "subsurface" refers to geological strata occurring below the earth's surface.
[0067] [0067] The term "subsurface gap" refers to a formation or a portion of a formation in which formation fluids may reside. The fluids can be, for example, hydrocarbon liquids, hydrocarbon gases, aqueous fluids, or combinations thereof.
[0068] [0068] As used here, the term “well hole” refers to a hole in the subsurface manufactured by drilling or inserting a conduit in the subsurface. A borehole can have a substantially circular cross section, or another shape in cross section. As used here, the term "well," when referring to an opening in the formation, can be used interchangeably with the term "well bore."
[0069] [0069] The terms "tubular member" or "tubular body" refer to any tube or tubular device, such as a liner junction or base tube, a portion of a seal liner, or a short tube.
[0070] [0070] The term "sand control device" means any elongated tubular body that allows an influx of fluid into an internal hole or a base tube while filtering out predetermined sizes of sand, fines and granular waste from an adjacent formation. A wire winding screen is an example of a sand control device.
[0071] [0071] The term "alternating flow channels" means any collection of piping and / or bypass tubes that provide fluid communication through or around a tubular well bore tool to allow a gravel slurry to bypass the tool well hole or any premature sand bridge in the annular region and continue packing with gravel still downstream. Examples of such well bore tools include (i) a plug having a sealing member, (ii) a sand screen or grooved tube, and (iii) a blank tube, with or without an external protective casing. Description of Specific Embodiments
[0072] [0072] The inventions are described here in relation to certain specific embodiments. However, as the following detailed description is specific to a particular embodiment or a particular use, it is intended to be illustrative only and should not be construed as limiting the scope of the inventions.
[0073] [0073] Certain aspects of the inventions are also described in relation to various figures. In some of the figures, the top of the drawing page is intended to be facing the surface, and the bottom of the drawing page is facing the bottom of the well. Although wells are commonly completed in substantially vertical orientation, it is understood that the wells can also be tilted and or even horizontally completed. When the descriptive terms "above and below" or "upper" and "lower" or similar terms are used in reference to a drawing or in the claims, they are intended to indicate the relative location on the drawing page or with respect to claim terms , and not necessarily orientation in the ground, since the present inventions are useful no matter how the well bore is oriented.
[0074] [0074] Figure 1 is a cross-sectional view of an illustrative well hole 100. The well hole 100 defines a hole 105 extending from a surface 101, and in the subsurface of the earth 110. The well hole 100 it is completed to have an open hole portion 120 at a lower end of the well hole 100. The well hole 100 was formed for the purpose of producing hydrocarbons for processing or commercial sale. A production pipeline line 130 is provided in bore 105 to transport production fluids from open hole portion 120 to surface 101.
[0075] [0075] Well hole 100 includes a well tree, shown schematically in 124. Well tree 124 includes a shut-off valve 126. Shut-off valve 126 controls the flow of production fluids from well bore 100 In addition, a subsurface safety valve 132 is provided to block the flow of fluids from production piping 130 in the event of a rupture or catastrophic event above the subsurface safety valve 132. The well bore 100 can optionally have a pump (not shown) in or just above open hole portion 120 to artificially suspend production fluids from open hole portion 120 to well tree 124.
[0076] [0076] The borehole of well 100 has been completed by fitting a series of tubes to subsurface 110. These tubes include a primary coating column 102, sometimes known as a surface coating or a conductor. These tubes also include at least one secondary casing column 104 and one tertiary 106. These casing columns 104, 106 are intermediate casing columns that provide support for the well hole walls 100. Intermediate casing columns 104, 106 can be trapped from the surface, or they can be attached to a next top coat column using an expandable seal liner or seal liner suspension device. It is understood that a tube column that does not extend back to the surface (such as coating column 106) is commonly referred to as a "seal coating."
[0077] [0077] In the bore arrangement of the illustrative well in Figure 1, the intermediate lining column 104 is secured from the surface 101, while the lining column 106 is secured from a lower end of the lining column 104. Additional intermediate coatings (not shown) can be used. The present inventions are not limited to the type of coating arrangement used.
[0078] [0078] Each coating column 102, 104, 106 is adjusted in place through a cement column 108.
[0079] [0079] The cement column 108 isolates the various formations of the subsurface 110 from the well bore 100 and one from the other. The cement column 108 extends from the surface 101 to a depth "L" at a lower end of the coating column 106. It is understood that some intermediate coating columns may not be completely cemented.
[0080] [0080] An annular region 136 is formed between the production pipe 130 and the casing column 106. A production plug 138 seals the annular region 136 near the lower end "L" of the casing column 106.
[0081] [0081] In many well holes, a final coating column known as the production coating is cemented in place to a depth where subsurface production intervals reside. In the meantime, the hole in the illustrative well 100 is completed as an open hole well. Consequently, the well hole 100 does not include a final coating column along the open hole portion 120.
[0082] [0082] In the hole of the illustrative well 100, the open hole portion 120 crosses three different subsurface intervals. These are indicated as upper range 112, intermediate range 114, and lower range 116. The upper range 112 and the lower range 116 may, for example, contain valuable oil deposits sought to be produced, while the intermediate range 114 may contain mainly water or another aqueous fluid within its pore volume. This may be due to the presence of native water zones, streaks of high permeability or natural fractures in the aquifer, or management of injection wells. In this example, there is a likelihood that water will invade well 100.
[0083] Alternatively, the upper 112 and intermediate 114 ranges may contain hydrocarbon fluids sought to be produced, processed and sold, while the lower range 116 may contain some oil along with constantly increasing amounts of water. This may be due to the taper, which is an elevation of hydrocarbon-water contact near the well. In this example, there is again the possibility that water will invade well 100.
[0084] Alternatively, the upper 112 and lower 116 ranges may be producing hydrocarbon fluids from a sand or other permeable rock matrix, while the intermediate gap 114 may represent a non-permeable shale or otherwise be substantially fluid impervious.
[0085] [0085] In any of these events, it is desirable that the operator isolate selected intervals. In the first example, the operator will want to isolate the intermediate range 114 from the production column 130 and the upper ranges 112 and lower 116 so that mainly hydrocarbon fluids can be produced through the well bore 100 and at the surface 101. In the second example, the operator will eventually want to isolate the lower gap 116 of the production column 130 and the upper gap 112 and intermediate 114 so that mainly hydrocarbon fluids can be produced through the well bore 100 and the surface 101. In the third example, the operator will want isolating the upper range 112 from the lower range 116, but there is no need to isolate the intermediate range 114. Solutions to these needs in the context of an open hole completion are provided here, and are demonstrated more fully in relation to the procedure drawings.
[0086] [0086] Regarding the production of hydrocarbon fluids from a well hole having an open hole completion, it is not only desirable to isolate selected intervals, but also to limit the influx of sand and other fine particles. In order to prevent the migration of particles from the formation in the production column 130 during operation, sand control devices 200 were conducted in the borehole of the well 100. These are described more fully below in relation to Figure 2 and with Figures 6A a 6N.
[0087] [0087] Referring now to Figure 2, the sand control devices 200 contain an elongated tubular body referred to as a base tube 205. The base tube 205 is typically composed of a plurality of tube joints. The base tube 205 (or each tube junction making up the base tube 205) typically has small perforations or grooves to allow influx of production fluids.
[0088] [0088] Sand control devices 200 also contain a filter medium 207 wrapped or otherwise placed radially around the base tubes 205. The filter medium 207 can be a wire mesh or wire wrap adjusted around the base tube 205. Alternatively, the filtration medium of the sand screen may comprise a membrane screen, an expandable screen, a sintered metal screen, a porous medium made of shape memory polymer (such as that described in U.S. Pat. No. 7,926,565), a porous medium packed with fibrous material, or a pre-packed solid particle bed. Filter medium 207 prevents the influx of sand or other particles above a predetermined size into the base pipe 205 and the production pipe 130.
[0089] [0089] In addition to the sand control devices 200, the well hole 100 includes one or more plug assemblies 210. In the illustrative arrangement of Figures 1 and 2, the well hole 100 has an upper plug assembly 210 'and a 210 ”lower plug assembly. However, additional shutter assemblies 210 or just one shutter assembly 210 can be used. The plug assemblies 210 ', 210 ”are uniquely configured to seal an annular region (seen in 202 of Figure 2) between the various sand control devices 200 and an adjacent wall 201 of the open hole portion 120 of the bore of the well 100.
[0090] [0090] Figure 2 provides an enlarged cross-sectional view of the open hole portion 120 of the well hole 100 of Figure 1. The open hole portion 120 and the three intervals 112,114,116 are most clearly observed. The upper 210 'and lower 210' plug assemblies are also more clearly visible near the upper and lower limits of the intermediate range 114, respectively. Gravel was placed within ring region 202. Finally, sand control devices 200 along each of the intervals 112, 114, 116 are shown.
[0091] [0091] With respect to the plug assemblies alone, each plug assembly 210 ’, 210” can have two separate shutters. The shutters are preferably adjusted through a combination of mechanical manipulation and hydraulic forces. For the purposes of this disclosure, the shutters are referred to as mechanically adjusted shutters. Illustrative plug assemblies 210 represent an upper plug 212 and a lower plug 214. Each plug 212, 214 has an expandable portion or element made of an elastomeric material or a thermoplastic material capable of providing at least one temporary fluid seal against a wall adjacent to well 201.
[0092] [0092] The elements for the top 212 and bottom 214 shutters must be able to withstand the pressures and loads associated with a gravel packing process. Typically, such pressures are about 2,000 psi to 5,000 psi. The elements for shutters 212, 214 must also withstand pressure and load due to differential well and / or reservoir bore pressures caused by natural failures, suppression, production, or injection. Production operations may involve selective production or allocation of production to meet regulatory needs. Injection operations may involve selective fluid injection to maintain strategic reservoir pressure. Injection operations can also involve selective stimulation in acid billing, acidification of the matrix, or removal of damage to the formation.
[0093] [0093] The surface or sealing elements for the mechanically adjusted shutters 212, 214 need only be in the order of inches in order to affect a suitable hydraulic seal. In one aspect, the elements are all about 6 inches (15.2 cm) to about 24 inches (61.0 cm) in length.
[0094] [0094] It is preferred that the elements of the shutters 212, 214 are capable of expanding to at least an 11 inch (about 28 cm) outer diameter surface, with no more than an ovality ratio of 1.1. The shutter elements 212, 214 should preferably be able to handle landslides in an open-hole section of 8-1 / 2 inches (about 21.6 cm) or 9-7 / 8 inches (about 25.1 cm) ). The expandable portions of the shutters 212, 214 will assist in maintaining at least one temporary seal against the wall 201 of the intermediate gap 114 (or other gap) as the pressure increases during the gravel packing operation.
[0095] [0095] The upper shutters 212 and lower 214 are adjusted before a gravel packing installation process. The elements of the upper 212 and lower 214 shutters are expanded in contact with the adjacent wall 201 in order to span the annular region 202 at a selected depth along the completion of open hole 120.
[0096] [0096] Figure 2 shows a 215 mandrel on shutters 212, 214. The mandrel serves as a base tube to support the expandable elastomeric elements.
[0097] [0097] As a "support" for the expandable shutter elements within the upper 212 and lower 214 shutters, the shutter assemblies 210 ', 210 "also all include an intermediate shutter element 216. The intermediate shutter element 216 defines a swelling elastomeric material made of synthetic rubber compounds. Suitable examples of swellable materials can be found in Easy Well Solutions' Constrictor® or SwellPacker®, and SwellFix’s E-ZIP®. The swellable plug 216 can include an swellable polymer or swellable polymer material, which is known to those skilled in the art and which can be adjusted by one of a conditioned drilling fluid, a completion fluid, a production fluid, a injection, a stimulation fluid, or any combination of these.
[0098] [0098] The intumescent plug element 216 is preferably attached to the outer surface of mandrel 215. The intumescible plug element 216 is allowed to expand over time when contacted by hydrocarbon fluids, formation water, or any chemical described above. which can be used as a driving fluid. As the plug element 216 expands, it forms a fluid seal with the adjacent zone, for example, gap 114. In one aspect, a sealing surface of the swellable packaging element 216 is about 5 feet (1.5 meters) ) to 50 feet (15.2 meters) in length; and more preferably, about 3 feet (0.9 meters) to 40 feet (12.2 meters) in length.
[0099] [0099] The intumescible plug element 216 must be able to expand into the hole wall of well 201 and provide the necessary pressure integrity in this expansion ratio. Since intumescent shutters are typically fitted to a shale section that may not produce hydrocarbon fluids, it is preferable to have a swelling elastomer or other material that may swell in the presence of forming water or an aqueous-based fluid. Examples of materials that will swell in the presence of an aqueous-based fluid are bentonite clay and a nitrile-based polymer with incorporated water-absorbing particles.
[0100] [0100] Alternatively, the intumescible plug element 216 can be manufactured from a combination of materials that swell in the presence of water and oil, respectively. Stated differently, the swelling plug 216 may include two types of swelling elastomers - one for water and one for oil. In this situation, the water-swellable element will swell when exposed to water-based gravel packaging fluid or in contact with forming water, and the oil-based element will expand when exposed to hydrocarbon production. An example of an elastomeric material that will swell in the presence of a hydrocarbon liquid is an oleophilic polymer that absorbs hydrocarbons in its matrix. The swelling occurs from the absorption of hydrocarbons, which also lubricates and decreases the mechanical strength of the polymer chain as it expands. Ethylene propylene diene monomer rubber (class M), or EPDM, is an example of such a material.
[0101] [0101] The swellable plug 216 can be manufactured from another expandable material. One example is a shape memory polymer. U.S. Pat. No. 7,243,732 and U.S. Pat. No. 7,392,852 disclose the use of such a material for zonal isolation.
[0102] [0102] The mechanically adjusted plug elements 212, 214 are preferably fitted in a water-based gravel packaging fluid that would be deflected around the intumescible plug element 216, such as through bypass tubes (not shown in Figure 2). If only a hydrocarbon swelling elastomer is used, the expansion of the element may not occur until after the failure of any of the mechanically adjusted plug elements 212, 214.
[0103] [0103] Upper 212 and lower 214 shutters can generally be of identical images to each other, except for the release sleeves that shear the respective shear pins or other latching mechanisms. The unilateral movement of a displacement tool (shown and discussed in relation to Figures 7A and 7B) will allow shutters 212, 214 to be activated in sequence or simultaneously. The lower plug 214 is activated first, followed by the upper plug 212 as the displacement tool is pulled up through an internal mandrel (shown and discussed in relation to Figures 6A and 6B). A short spacing is preferably provided between upper 212 and lower 214 shutters.
[0104] [0104] Shutter assemblies 210 ’, 210” help to control and manage fluids produced from different zones. In this regard, the plug assemblies 210 ’, 210” allow the operator to seal a production or injection interval, depending on the function of the well. Installing the 210 ', 210 ”plug assemblies at the initial completion allows an operator to stop the production of one or more zones during the life of the well to limit water production or, in some instances, an undesirable non-condensable fluid such as hydrogen sulfide. Shutter assemblies 210 ’, 210” work in new conjunction with a transposition shutter, a plug, or, as described below, an insulation column to control the flow of the subsurface intervals.
[0105] [0105] Shutters have historically not been installed when an open-hole gravel package is used because of the difficulty in forming a complete gravel package above and below the obturator. Related patent applications, U.S. Publications Nos. 2009/0294128 and 2010/0032158 disclose apparatus' and methods for gravel packing of an open hole well after a shutter has been adjusted to a completion interval.
[0106] [0106] Certain technical challenges remained with respect to the methods disclosed in Pub. U.S. Nos. 2009/0294128 and 2010/0032158, particularly in relation to the shutter. Orders declare that the plug can be a hydraulically driven inflatable element. Such an inflatable element can be made of an elastomeric material or a thermoplastic material. However, designing a plug element from such materials requires that the plug element meets a particularly high level of performance. In this regard, the plug element must be able to maintain zonal insulation for a period of years in the presence of high pressures and / or high temperatures and / or acidic fluids. As an alternative, orders declare that the plug can be a swelling rubber element that expands in the presence of hydrocarbons, water, or other stimulus. However, known swelling elastomers typically require about 30 days or more to fully expand in sealed fluid engagement with the adjacent rock formation. Therefore, improved shutters and zonal isolation devices' are offered here.
[0107] [0107] Figure 3A shows an illustrative plug assembly 300 providing an alternate flow path for a gravel slurry. The shutter assembly 300 is generally seen in lateral view in cross section. The plug assembly 300 includes several components that can be used to seal an annular space along the open hole portion 120.
[0108] [0108] The plug assembly 300 first includes a main body section 302. The main body section 302 is preferably made of steel or steel alloys. The main body section 302 is configured to be a specific length 316, such as about 40 feet (12.2 meters). The main body section 302 comprises individual pipe joints that will be between 10 feet (3.0 meters) and 50 feet (15.2 meters) in length. The tube joints are typically threaded connected end to end to form the main body section 302 according to length 316.
[0109] [0109] Shutter assembly 300 also includes optically mechanically adjusted shutters 304. Mechanically adjusted shutters 304 are shown schematically, and are generally in accordance with mechanically adjusted shutter elements 212 and 214 of Figure 2. Shutters 304 preferably include elastomeric elements of the cup type that are less than 1 foot (0.3 meters) in length. As described below, the shutters 304 have alternating flow channels that uniquely allow the shutters 304 to be adjusted before a gravel slurry is circulated in the well bore.
[0110] [0110] The shutter assembly 300 also optionally includes an intumescible shutter 308. The intumescible shutter 308 conforms to the intumescible shutter element 216 of Figure 2. The intumescible shutter 308 is preferably about 3 feet (0.9 meters) a 40 feet (12.2 meters) in length. Together, the mechanically adjusted shutters 304 and the intermediate swellable plug 308 surround the main body section 302. Alternatively, a short spacing can be provided between the mechanically adjusted shutters 304 instead of the swellable plug 308.
[0111] [0111] The plug assembly 300 also includes a plurality of bypass tubes. Bypass tubes are observed in spectrum at 318. Bypass tubes 318 can also be referred to as transport tubes or alternating flow channels. Bypass tubes 318 are blank sections of tube having a length that extends along the length 316 of mechanically adjusted shutters 304 and intumescible plug 308. Bypass tubes 318 in plug assembly 300 are configured to couple and form a seal with bypass tubes on connected sand screens, as discussed below.
[0112] [0112] Bypass tubes 318 provide an alternating flow path through mechanically adjusted shutters 304 and intermediate intumescent shutter 308 (or spacing). This allows the bypass tubes 318 to carry a carrier fluid along with gravel at different intervals 112, 114 and 116 from the open hole portion 120 of the well hole 100.
[0113] [0113] The shutter assembly 300 also includes connection members. These can represent traditional screw couplings. First, a narrow section 306 is provided at a primary end of the plug assembly 300. The narrow section 306 has external threads to connect with a threaded connection box of a sand screen or other pipe. Thereafter, a notched or externally threaded section 310 is provided at an opposite secondary end. The threaded section 310 serves as a connection box for receiving an external threaded end of a sand screen or other tubular member.
[0114] [0114] The narrow section 306 and the threaded section 310 can be made of steel or alloy steel. Narrow section 306 and threaded section 310 are all configured to be a specific length 314, such as 4 inches (10.2 cm) to 4 feet (1.2 meters) (or other suitable distance). The narrow section 306 and the threaded section 310 also have specific internal and external diameters. The narrow section 306 has external threads 307, while the threaded section 310 has internal threads 311. These threads 307 and 311 can be used to form a seal between the plug assembly 300 and sand control devices or other pipe segments.
[0115] [0115] A cross-sectional view of the shutter assembly 300 is shown in Figure 3B. Figure 3B is taken along line 3B-3B in Figure 3A. In Figure 3B, the intumescible plug 308 is observed circumferentially arranged around the base tube 302. Several bypass tubes 318 are placed radially and equidistantly around the base tube 302. A central hole 305 is shown inside the tube base 302. Central bore 305 receives production fluids during production operations and transports them to production piping 130.
[0116] [0116] Figure 4A shows a side view in cross section of a 400 zone isolation device, in one embodiment. The zonal isolation apparatus 400 includes the plug assembly 300 from Figure 3A. In addition, sand control devices 200 were connected at opposite ends to the narrow section 306 and the notched section 310, respectively. Bypass tubes 318 from plug assembly 300 are observed connected to bypass tubes 218 in sand control devices 200. Bypass tubes 218 represent the packaging tubes, which allow the flow of gravel slurry between an annular borehole space and tubes 218. Bypass tubes 218 in sand control devices 200 optionally include valves 209 for controlling gravel slurry flow, such as packaging tubes (not shown ).
[0117] [0117] Figure 4B provides a side view in cross section of the zonal isolation device 400. Figure 4B is taken along line 4B-4B of Figure 4A. This is cut through one of the sand screens 200. In Figure 4B, the slotted or perforated base tube 205 is observed. This is in accordance with the base tube 205 of Figures 1 and 2. A central hole 105 is shown inside the base tube 205 to receive production fluids during production operations.
[0118] [0118] An outer mesh 220 is disposed immediately around the base tube 205. The outer mesh 220 preferably comprises a wire mesh or mesh helically wound around the base tube 205, and serves as a screen. In addition, bypass tubes 218 are placed radially and equidistant around outer mesh 205. This means that sand control devices 200 provide an external embodiment for bypass tubes 218 (or alternating flow channels) .
[0119] [0119] The configuration of the bypass tubes 218 is preferably concentric. This is seen in the cross-sectional views of Figures 3B and 4B. However, bypass tubes 218 can be eccentrically designed. For example, Figure 2B in Pat. US No. 7,661,476 presents an "Prior Art" arrangement for a sand control device, in which the packaging tubes 208a and transport tubes 208b are placed external to the base tube 202 and the surrounding filter medium 204, forming an eccentric arrangement.
[0120] [0120] In the arrangement of Figures 4A and 4B, the bypass tubes 218 are external to the filter medium, or external mesh 220. However, the configuration of the sand control device 200 can be modified. In this regard, the bypass tubes 218 can be moved internally to the filter means 220.
[0121] [0121] Figure 5A shows a side view in cross section of a zonal isolation device 500, in an alternate embodiment. In this embodiment, the sand control devices 200 are again connected at ends opposite the narrow section 306 and the notched section 310, respectively, of the plug assembly 300. In addition, the bypass tubes 318 in the plug assembly 300 are observed connected to the bypass tubes 218 in the sand control assembly 200. However, in Figure 5A, the sand control assembly 200 uses internal bypass tubes 218, meaning that bypass tubes 218 are arranged between the base tube 205 and the surrounding filter means 220.
[0122] [0122] Figure 5B provides a side view in cross section of the zonal isolation device 500. Figure 5B is taken along the line B-B of Figure 5A. This is cut through one of the sand screens 200. In Figure 5B, the slotted or perforated base tube 205 is observed again. This is in accordance with base tube 205 of Figures 1 and 2. The central bore 105 is shown inside the base tube 205 to receive production fluids during production operations.
[0123] [0123] Bypass tubes 218 are placed radially and equidistant around base tube 205. Bypass tubes 218 are immediately present around base tube 205, and within a surrounding filter medium 220. This means that , the sand control devices 200 of Figures 5A and 5B provide an internal embodiment for the bypass tubes 218.
[0124] [0124] An annular region 225 is created between the base tube 205 and the outer mesh or surrounding filter medium 220. The annular region 225 accommodates the influx of production fluids into a well bore. The outer winding of wires 220 is supported by a plurality of radially extended support beams 222. The beams 222 extend through annular region 225.
[0125] [0125] Figures 4A and 5A show arrangements for connecting sand screens 200 to a shutter assembly. The bypass tubes 318 (or alternating flow channels) within the plug assembly 300, connect liquidly to the bypass tubes 218 along the sand screens 200. However, the zonal isolation device arrangements 400, 500 of Figures 4A- 4B and 5A-5B are illustrative only. In an alternative arrangement, a pipe system with multiple connections can be used to provide fluid communication between bypass tubes 218 and bypass tubes 318.
[0126] [0126] Figure 3C is a cross-sectional view of the plug assembly 300 of Figure 3A, in an alternate embodiment. In this arrangement, bypass tubes 318 are multiplied around base tube 302. A support ring 315 is provided around bypass tubes 318. It is again understood that the present apparatus and methods are not limited by the design and arrangement bypass tubes 318 in particular, provided that the slurry bypass is provided for the plug assembly 210. However, it is preferred that a concentric arrangement is used.
[0127] [0127] It should also be noted that the connection mechanism for the sand control devices 200 with the plug assembly 300 may include a sealing mechanism (not shown). The sealing mechanism prevents leakage of the slurry, which is in the alternating flow path formed by the bypass tubes. Examples of such sealing mechanisms are described in U.S. Patent No. 6,464,261; Pat. Intl. WO 2004/094769; Pat. Intl. WO 2005/031105; Publ. of Pat. No. 2004/0140089; Publ. of Pat. No. 2005/0028977; Publ. of Pat. No. 2005/0061501; and Publ. of Pat. No. 2005/0082060.
[0128] [0128] Connecting sand control devices 200 with a shutter assembly 300 requires alignment of bypass tubes 318 in shutter assembly 300 with bypass tubes 218 along the sand control devices 200. In this regard , the flow path of the bypass tubes 218 in the sand control devices must be uninterrupted when a shutter is engaged. Figure 4A (described above) shows the sand control devices 200 connected to an intermediate plug assembly 300, with the bypass tubes 218, 318 in alignment. However, making this connection typically requires a special replacement or jumper with a union type connection, a regulated connection to align the multiple tubes, or a cylindrical cover plate over the connection tubes. These connections are expensive, time consuming, and / or difficult to handle on the platform floor.
[0129] [0129] U.S. Patent No. 7,661,476, entitled "Gravel Packing Methods", discloses a production column (referred to as a joint assembly) that employs one or more sand mesh joints. The sand screen joints are placed between a "load sleeve assembly" and a "torque sleeve assembly". The load sleeve assembly defines an elongated body comprising an outer wall (serving as an outer diameter) and an inner wall (providing an inner diameter). The inner wall forms a hole through the loading sleeve assembly. Similarly, the torque sleeve assembly defines an elongated body comprising an outer wall (serving as an outer diameter) and an inner wall (providing an inner diameter). The inner wall also forms a hole through the fitting of the torque sleeve.
[0130] [0130] The loading sleeve assembly includes at least one transport channel and at least one packaging channel. The at least one transport channel and the at least one packaging channel are arranged external to the inner diameter and internal to the outer diameter. Similarly, the torque sleeve assembly includes at least one channel. The at least one channel is disposed external to the internal diameter and internal to the external diameter.
[0131] [0131] The production column includes a “main body portion”. This is essentially a base tube that leads through the sand screen. A connection assembly having a collecting region can also be provided. The collection region is configured to be in fluid flow communication with at least one transport channel and at least one packaging channel of the load sleeve assembly during at least a packaging portion with gravel operations. The connection assembly is operably connected to at least a portion of the at least one joint assembly on or near the load sleeve assembly. The load sleeve assembly and the torque sleeve assembly are composed or connected with the base tube in such a way that the transport and packaging channels are in fluid communication, thereby providing alternate flow channels for the slurry gravel fluid. The benefit of the load sleeve assembly, the torque sleeve assembly, and the connection assembly is that they allow a series of sand screen joints to be connected and driven into the well bore in a faster and less expensive way .
[0132] [0132] As noted, the shutter assembly 300 includes a pair of mechanically adjusted shutters 304. When using shutter assembly 300, shutters 304 are advantageously adjusted before the slurry is injected and the gravel packaging is formed. This requires a single shutter arrangement, in which the bypass tubes are supplied to an alternating flow channel.
[0133] [0133] The plugs 304 of Figure 3A are shown schematically. However, details regarding the suitable shutters for a zonal isolating gravel packing apparatus are described in the previous patent documents. For example, Pat. No. 5,588,487 entitled "Tool for Blocking Axial Flow in Gravel-Packed Well Annulus", describes a well screen having pairs of shutter elements. The pit screen includes bypass tubes that allow a gravel slurry to bypass pairs of plug elements during a gravel packing procedure. Also, Pat. Prov. No. 61 / 424,427, entitled "Packer for Alternate Path Gravel Packing, and Method for Completing a Wellbore", describes a mechanically adjusted shutter that can be driven into a well bore with a sand screen. The shutter includes alternating flow channels that allow a gravel slurry to bypass the associated shutter elements. The shutter is preferably adjusted before a gravel packing procedure is carried out. The obturators can additionally include an intumescent obturator element as described above, as long as they incorporate a bypass tube for loading the gravel slurry in addition to the intumescible obturator during packaging with gravel.
[0134] [0134] It is preferred that the plug is a plug assembly comprising at least one mechanically adjusted plug. Each mechanically adjusted plug includes a sealing element, an internal mandrel, and at least one alternating flow channel. The alternating flow channel is in fluid communication with alternating flow channels on a sand screen. The shutter assembly is connected to the sand screen before or at the insertion time.
[0135] [0135] In the preferred arrangement of Pat. Prov. No. 61 / 424,427, the shutters all have a piston housing. The piston housing is held in place along a piston mandrel during insertion. The piston housing is secured using a release sleeve and a release key. The release sleeve and release key prevent relative translational movement between the piston housing and the piston mandrel.
[0136] [0136] After insertion, the plugs are mechanically adjusted by shearing the shear pin and sliding the release sleeve. This, in turn, releases the release key, which then allows the hydrostatic pressure to act downstream against the piston housing. The piston housing moves in relation to the piston mandrel. In one aspect, after the shear pins have been cut, the piston housing slides along an external surface of the piston mandrel. The piston housing then acts on a centralizer. The centralizer can be, for example, as described in WO 2009/071874, entitled “Improved Centraliser”.
[0137] [0137] As the piston housing moves along the inner mandrel, it also applies a force against the packaging element. The centralizer and expandable packaging elements of the shutters expand against the borehole wall.
[0138] [0138] The shutters can be adjusted using an adjustment tool that is driven into the well bore with a wash pipe. The adjustment tool can simply be a profiled portion of the wash tubing body for the gravel packaging operation. Preferably, however, the adjustment tool is a separate tubular body that is screwed onto the wash tubing. Such an adjustment tool is shown and described in Figure 7C of the Pat. Prov. No. 61 / 424,427.
[0139] [0139] With respect to sand control devices 200, various embodiments of sand control devices 200 can be used with the apparatus and methods in this report. For example, sand control devices can include stand-alone screens (SAS), pre-packaged screens, or membrane screens. The joints can be any combination of screen, empty tube, or zonal isolation device.
[0140] [0140] Once the shutter 304 is adjusted, packing with gravel operations can begin. Figures 6A through 6N show stages of a gravel packing procedure, in one embodiment. The gravel packaging procedure uses a shutter assembly having alternating flow channels. The shutter assembly may be in accordance with shutter assembly 300 of Figure 3A. The shutter assembly 300 will have mechanically adjusted shutters 304. These mechanically adjusted shutters can again be in accordance with the shutter described in Pat. Prov. No. 61 / 424,427 filed December 17, 2010, for example.
[0141] [0141] In Figures 6A through 6N, the sand control devices are used in a packaging procedure with illustrative gravel in a conditioned drilling mud. The conditioned drilling mud can be a non-aqueous fluid (NAF), such as an oil-based fluid with solids. Optionally, a water-based fluid with solids is also used. This process, which is a two-fluid process, may include techniques similar to the process discussed in Pat. International No. WO / 2004/079145 and related to Pat. No. 7,373,978, each of which is incorporated herein by reference. However, it should be noted that this example is simply for illustrative purposes, as other suitable processes and fluids can be used.
[0142] [0142] In Figure 6A, a well hole 600 is shown. The illustrative well bore 600 is a horizontal open bore hole. The well hole 600 includes a wall 605. Two different production intervals are indicated along the horizontal well hole 600. These are shown in 610 and 620. Two sand control devices 650 were driven into the well hole 600. The separate sand control devices 650 are provided in each production interval 610, 620.
[0143] [0143] Each of the sand control devices 650 is comprised of a base tube 654 and a surrounding sand screen 656. Base tubes 654 have grooves or perforations to allow fluid to flow into the base tube 654. The base tubes 654 are provided in a series of separate joints that are preferably about 30 feet (9.14 meters) in length. Sand control devices 650 also include alternate flow paths. These can be in accordance with the bypass tubes 218 of Figure 4B or Figure 5B. Preferably, the bypass tubes are internal bypass tubes arranged between the base tubes 654 and the sand screens 656 along the annular region shown in 652.
[0144] [0144] Sand control devices 650 are connected via an intermediate shutter assembly 300. In the arrangement in Figure 6A, shutter assembly 300 is installed at the interface between production intervals 610 and 620. More than one shutter assembly 300 can be incorporated. The connection between sand control devices 650 and a plug assembly 300 may be in accordance with U.S. Patent No. 7,661,476, discussed above.
[0145] [0145] In addition to the sand control devices 650, a washing pipe 640 has been lowered into the hole of the well 600. The washing pipe 640 is conducted into the hole of the well 600 below a cross tool or a packaging service tool. with gravel (not shown) that is attached to the end of a 635 drill pipe or other work line. The wash tubing 640 is an elongated tubular member that extends into the sand screens 656. The wash tubing 640 assists in the circulation of the gravel slurry during a gravel packaging operation, and is subsequently removed. Attached to the wash pipe 640 is a displacement tool 655. The displacement tool 655 is positioned below the plug assembly 300. The displacement tool is used to activate the shutters 304.
[0146] [0146] In Figure 6A, a transversal tool 645 is placed at the end of drilling pipe 635. The transversal tool 645 is used to direct the injection and circulation of the gravel slurry, as discussed in more detail below.
[0147] [0147] A separate plug 615 is connected to the transverse tool 645. The plug 615 and the connected transverse tool 645 are temporarily positioned within a production liner 630. Together, the plug 615, the transverse tool 645, the elongated wash 640, displacement tool 655, and packaging with gravel screens 656 are conducted at the lower end of the well bore 600. Shutter 615 is fitted to production liner 630. Transverse tool 645 is selectively moved between positions of front and reverse circulation.
[0148] [0148] Returning to Figure 6A, a conditioned NAF (or other drilling mud) 614 is placed in the well hole 600. The term “conditioned” means that the drilling mud has been filtered or otherwise cleaned. Drilling mud 614 can be conditioned on mesh agitators (not shown) before sand control devices 650 are driven into well bore 600 to reduce any potential buffer from sand control devices 650. Preferably, conditioned drilling 614 is deposited in the well hole 600 and released to the open hole portion before the drilling column 635, the connected sand screens 656 and the wash pipe 640 are driven into the well hole 600.
[0149] [0149] In Figure 6B, the plug 615 is fitted to the production column liner 630. This means that the plug 615 is actuated to extend the slips and an elastomeric sealing element against the adjacent liner column 630. The plug 615 is set above the 610 and 620 intervals, which must be packed gravel. Shutter 615 seals the gaps 610 and 620 from the bore portions of well 600 above shutter 615.
[0150] [0150] After the plug 615 is adjusted, as shown in Figure 6C, the transverse tool 645 is moved upwards in a reverse position. Circulation pressures can be taken in this position. A fluid carrier 612 is pumped onto drill pipe 635 and placed in an annular space between drill pipe 635 and the surrounding production liner 630 above plug 615. The fluid carrier is a gravel fluid carrier, which is the liquid component of the gravel packaging slurry. Fluid loader 612 displaces conditioned drilling fluid 614 above plug 615, which again can be an oil-based fluid, such as conditioned NAF. The fluid carrier 612 moves the drilling fluid 614 in the direction indicated by the arrows “C.”
[0151] [0151] Then, in Figure 6D, the transverse tool 645 is replaced back in a forward position. This is the position used to circulate the gravel packaging slurry in the open hole portion of the well hole, and is sometimes referred to as the gravel packaging position. The pre-loaded fluid carrier 612 is pumped under the annular space between the drill pipe 635 and the production liner 630. The fluid carrier 612 is further pumped under the wash pipe 640. This pushes the conditioned drilling mud 614 below the washing pipe 640, outside the sand screens 656, sweeping the open hole annular space between the sand screens 656 and the adjacent wall 605 of the open hole portion of the well hole 600, through the transverse tool 645, and behind drilling pipe 635. The flow path of fluid carrier 612 is again indicated by the arrows “C.”
[0152] [0152] In Figures 6E through 6G, the production intervals 610, 620 are prepared for packing with gravel.
[0153] [0153] In Figure 6E, once the annular bore space opened between the sand screens 656 and the adjacent wall 605 has been swept with the fluid carrier 612, the transverse tool 645 is moved back to the reverse circulation circulation. Conditioned drilling fluid 614 is pumped down the annular space between drilling pipe 635 and production liner 630 to force fluid carrier 612 out of drilling pipe 635, as shown by the arrows “D.” These fluids can be removed from the 635 drill pipe.
[0154] [0154] Then, the 304 shutters are adjusted, as shown in Figure 6F. This is done by pulling the displacement tool 655 located below the plug assembly 300 on the wash pipe 640 and above beyond the plug assembly 300. More specifically, the mechanically adjusted shutters 304 of the plug assembly 300 are adjusted. The 304 shutters can be, for example, the shutter described in U.S. Pat. Prov. No. 61 / 424,427. Shutters 304 are used to isolate the annular space formed between the sand screens 656 and the adjacent wall 605 of the well hole 600.
[0155] [0155] The wash pipe 640 is lowered to a reverse position. While in the reverse position, as shown in Figure 6G, the gravel fluid carrier 616 can be placed inside the drill pipe 635 and used to force the fluid carrier 612 above the annular space formed between the drill pipe 635 and the production liner 630 above plug 615. Reverse circulation of the fluid carrier is shown by the arrows “C.”
[0156] [0156] In Figures 6H to 6J, the transversal tool 645 can be moved in the forward circulation position (or gravel packing position) to gravel the primary subsurface gap 610 with gravel.
[0157] [0157] In Figure 6H, the gravel fluid loader 616 begins to create a gravel package within the production range 610 above the plug assembly 300 in the annular space between the sand screen 656 and the well hole wall 605 open hole 600. The fluid seeps out of the sand screen 656 and returns through the wash pipe 640 as indicated by the arrows “D.” The fluid carrier 612 in the annular space of the well hole is forced into the screen, through the wash pipe 640, and above the annular space formed between the drill pipe 635 and the production liner 630 above the plug 615.
[0158] [0158] In Figure 6I, a first packing with gravel 660 begins to form above the plug 300. The packing with gravel 660 is forming around the sand screen 656 and towards the plug 615. The fluid carrier 612 is circled below from the plug assembly 300 and to the bottom of the well hole 600. The fluid carrier 612 without gravel flows above the wash pipe 640 as indicated by the arrows “C.”
[0159] [0159] In Figure 6J, the gravel packing process continues to form the gravel packing 660 towards the shutter 615. The sand screen 656 is now being completely covered by the gravel packing 660 above the shutter assembly 300. The fluid carrier 612 continues to be circulated below the plug assembly 300 and at the bottom of the well hole 600. The fluid carrier 612 without gravel flows above the wash pipe 640 as again indicated by the arrows “C.”
[0160] [0160] Since the gravel packing 660 is formed in the first gap 610 and the sand screens above the plug assembly 300 are covered with gravel, the gravel fluid loader 616 is forced through the bypass tubes (such as the bypass tubes 318 in Figure 3B). The gravel fluid carrier 616 forms the gravel packaging 660 in Figures 6K to 6N.
[0161] [0161] In Figure 6K, the gravel fluid loader 616 now flows within the production range 620 below the plug assembly 300. The fluid loader 616 flows through the bypass tubes and plug assembly 300, and then out of the sand screen 656. The fluid carrier 616 then flows into the annular space between the sand screen 656 and the wall 605 of the borehole 600, and returns through the wash pipe 640. The flow of the fluid carrier with gravel 616 is indicated by the arrows “D,” while the flow from the fluid carrier in the washing pipe 640 without the gravel is indicated at 612, shown by the arrows “C”.
[0162] [0162] It is noted in this report that the slurry only flows through the bypass channels along the sections of the shutter. After that, the slurry will follow in alternating flow channels at the next, adjacent screen junction. The alternating flow channels have transport and packaging tubes multiplied together at each end of a screen joint. The packaging tubes are supplied along the sand mesh joints. The packaging tubes represent side nozzles that allow the slurry to fill any voids in the annular space. The transport tubes will take the slurry further downstream.
[0163] [0163] In Figure 6L, the gravel packing 660 is starting to form below the shutter assembly 300 and around the sand screen 656. In Figure 6M, the gravel packing 660 continues to grow from the bottom of the hole from well 600 upward towards plug assembly 300. In Figure 6N, gravel packing 660 was formed from the bottom of well hole 600 to plug assembly 300. The sand screen 656 below the plug assembly 300 was covered by packing with gravel 660. The surface treatment pressure increases to indicate that the annular space between the sand screens 656 and the wall 605 of the well bore 600 is completely packed with gravel.
[0164] [0164] Figure 60 shows drill column 635 and wash pipe 640 of Figures 6A to 6N has been removed from well hole 600. Sheath 630, base tubes 654, and sand screens 656 remain in the well bore 600 over the upper production intervals 610 and lower 620. The shutter assembly 300 and the gravel packaging 660 remain fitted in the hole of the open-hole well 600 following completion of the gravel packaging procedure of the Figures 6A to 6N. The well bore 600 is now ready for production operations.
[0165] [0165] As mentioned above, once a well hole has been packed with gravel, the operator can choose to isolate a selected gap in the well hole, and suspend production from that gap. To demonstrate how a well hole interval can be isolated, Figures 7A and 7B are provided.
[0166] [0166] First, Figure 7A is a cross-sectional view of a well hole 700A. The borehole of well 700A is generally constructed according to the borehole of well 100 in Figure 2. In Figure 7A, the borehole of well 700A is shown intersecting through a subsurface gap 114. The gap 114 represents an intermediate gap. This means that there is also an upper range 112 and a lower range 116 (seen in Figure 2, but not shown in Figure 7A).
[0167] [0167] Subsurface interval 114 may be a portion of a subsurface formation that once produced hydrocarbons in commercially viable quantities, but has now undergone significant hydrocarbon gas and water invasion. Alternatively, the subsurface gap 114 can be a formation that was originally an aqueous or aquifer zone or is otherwise substantially saturated with aqueous fluid. In both cases, the operator decided to seal off the inflow of formation fluids from interval 114 into the well bore 700A.
[0168] [0168] A sand screen 200 was placed in the well hole 700A. The sand screen 200 is in accordance with the sand control device 200 of Figure 2. In addition, a base tube 205 is observed extending through the intermediate gap 114. The base tube 205 is part of the sand screen 200. The sand screen 200 also includes a mesh screen, a wire mesh, or other circumferential filter means 207. The base tube 205 and the surrounding filter means 207 preferably comprise a series of joints connected end to end. The joints are ideally about 5 to 45 feet in length.
[0169] [0169] The well hole 700A has an upper plug assembly 210 'and a lower plug assembly 210 ”. The upper plug assembly 210 'is arranged close to the interface of the upper gap 112 and the intermediate gap 114, while the lower plug assembly 210 ”is arranged near the interface of the intermediate gap 114 and the lower gap 116. Each plug assembly 210 ', 210 ”is preferably in accordance with the plug assembly 300 of Figures 3A and 3B. In this regard, the plug assemblies 210 ', 210 ”will all have opposing mechanically adjusted shutters 304. The mechanically adjusted shutters are shown in Figure 7A at 212 and 214. Each of the mechanically adjusted shutters 212, 214 can be in accordance with shutters described in Pat. Prov. No. 61 / 424,427. The shutters 212, 214 are spaced apart, as shown by the spacing 216.
[0170] [0170] The well hole 700A is completed as an open hole completion. A gravel pack was placed in the well hole 700A to help protect against the influx of granular particles. The gravel packing is indicated as spackles in the annular space 202 between the filter medium 207 of the sand screen 200 and the adjacent wall 201 of the well hole 700A.
[0171] [0171] In the arrangement of Figure 7A, the operator wishes to continue producing forming fluids from upper 112 and lower 116 intervals while sealing outside the intermediate range 114. The upper 112 and lower 116 intervals are formed of sand or other rocky matrix that is permeable fluid flow. Alternatively, the operator wishes to suspend the injection of fluids in the intermediate range 114. To accomplish this, a transposition plug 705 has been placed inside the sand screen 200. The transposition plug 705 is placed substantially through the intermediate range 114 to prevent inflow of forming fluids (or the injection of fluids in) from the intermediate range 114.
[0172] [0172] The transposition plug 705 comprises a mandrel 710. Mandrel 710 is an elongated tubular body having an upper end adjacent to the upper plug assembly 210 ', and a lower end adjacent to the lower plug assembly 210 ”. The transposition shutter 700 also comprises a pair of annular shutters. These represent an upper plug 712 adjacent to the upper plug assembly 210 ', and a lower plug 714 adjacent to the lower plug assembly 210 ”. The new combination of the upper plug assembly 210 'with the upper plug 712, and the lower plug assembly 210 ”with the lower plug 714 allows the operator to successfully isolate a subsurface gap, such as the intermediate gap 114 at a completion of open hole.
[0173] [0173] Another technique for isolating a gap along an open hole formation is shown in Figure 7B. Figure 7B is a side view of a well hole 700B. The borehole of well 700B can again match the borehole of well 100 in Figure 2. In this report, the bottom gap 116 of the open hole completion is shown. The lower gap 116 extends essentially to the bottom 136 of the well bore 700B and is the lowest zone of interest.
[0174] [0174] In this example, subsurface gap 116 may be a portion of a subsurface formation that once produced hydrocarbons in commercially viable quantities, but has now undergone significant water or hydrocarbon gas invasion. Alternatively, subsurface gap 116 may be a formation that was originally an aqueous or aquifer zone or is otherwise substantially saturated with aqueous fluid. In both cases, the operator decided to seal off the inflow of forming fluids from the lower gap 116 into the well bore 700B.
[0175] [0175] Alternatively, the operator may wish to inject no more fluids in the lower range 116. In this case, the operator may again seal outside the lower range 116 from the well hole 700B.
[0176] [0176] To accomplish this, a plug 720 was placed inside the well hole 700B. Specifically, plug 720 has been fitted to mandrel 215 that supports the lower 210 ”plug assembly. Of the two plug assemblies 210 ', 210 ”, only the lower plug assembly 210” is observed. By positioning the plug 720 adjacent to the 210 ”lower plug assembly, the plug 720 is able to prevent the flow of formation fluids above the well hole 700B from the lower gap 116, or below the well hole 700B in the lower gap 116.
[0177] [0177] It is noted that, in relation to the arrangement of Figure 7B, the intermediate gap 114 may comprise a shale or other rocky matrix that is substantially impermeable to the flow of fluid. In this situation, the plug 720 does not need to be placed adjacent to the lower 210 ”plug assembly; instead, plug 720 can be placed anywhere above the lower gap 116 and along the intermediate gap 114. Furthermore, in this example, the upper plug assembly 210 'does not need to be positioned at the top of the intermediate gap 114; instead, the upper plug assembly 210 'can also be placed anywhere along the intermediate gap 114. If the intermediate gap 114 is comprised of unproductive shale, the operator may choose to place the empty tube through this region, with channels alternating flow flows, that is, transport tubes, along the intermediate interval 114.
[0178] [0178] The arrangements in Figures 7A and 7B provide a means to isolate the selected formations. However, any modification of the inflow control arrangements of Figures 7A and 7B will require removal of the downhole equipment, that is, the transposition plug 705 or the plug 720. This can be a difficult or expensive technique. Therefore, it is desirable to isolate the different subsurface intervals along a sand control device using a traditional inflow control device having bottom valves that can be controlled from the surface. In this way, the operator can selectively produce the forming fluids or inject fluids over a selected subsurface interval very readily. In other words, once a well hole has been packed with gravel, the operator can choose to isolate a selected gap in the well hole, and suspend production from that gap. To demonstrate how, a well hole interval can be isolated, provided in Figure 8.
[0179] [0179] Figure 8 is a schematic side view of a well hole 800. The well hole 800 is generally formed according to the well hole 100 of Figure 2. In this respect, the well hole 800 has a wall of well hole 201 formed to pass through an open hole portion 120. The open hole portion 120 includes illustrative subsurface intervals 112, 114, 116.
[0180] [0180] Sand control devices 200 have been placed along open hole portion 120 of well bore 800. Sand control devices 200 include base tubes 205 and filter medium 207. In addition, an assembly of upper plug 210 'and a lower plug assembly 210 ”were placed between the joints of the base tubes 205. As described above, the plug assemblies 210', 210” are uniquely configured to seal the annular region 202 between the various sand control devices 200 and the adjacent wall 201 of the well bore 800.
[0181] [0181] In order to control the flow of fluids between the well bore 800 and the various subsurface intervals 112, 114, 116, an insulation column 810 is provided. The 810 isolation column includes a series of 802 flow control valves along its length. Portions of the filter medium or sand screen 207 are cut to expose the valves 802. At least one of the valves 802 is placed above the upper plug assembly 210 '; at least one of the 802 valves is placed below the 210 ”lower plug assembly; and at least one of the valves 802 is placed intermediate to the upper 210 'and lower 210 "plug assemblies.
[0182] [0182] The insulating column 810 is preferably comprised of a series of tubular joints 805 in a threadable manner connected end to end. Tubular joints 805 form a tubular body having an internal diameter defining a hole in fluid communication with a hole in a pipe column 130. Tubular joints 805 also have an outer diameter configured to reside within the base tube 205 of the sand control 200 and inside mandrel 215 of shutter assemblies 210.
[0183] [0183] Some of the 805 joints will contain 802 flow control valves. The 802 flow control valves represent one or more direct ports provided through the 805 tubular joints. The 802 valves are controlled from the surface so that the 802 valves can be selectively opened and closed. 802 valves can be opened or closed in response to mechanical force, in response to an electrical signal, in response to an acoustic signal, in response to the passing of a radio frequency identification label (RFID), or in response to pressure from fluid supplied through hydraulic lines.
[0184] [0184] In one embodiment, the functionality of the insulation column 810 can be facilitated by incorporating certain commercially available products. These can include Halliburton’s DuraSleeve® or Halliburton’s Slimline Sliding Side-Door® (SSD). These may alternatively include Tendeka’s Reflo® or FloRight®. In one embodiment, and as shown in Figure 8, multiple flow control valves 802 can be placed across each subsurface interval 112, 114, 116. All, or only a portion of the flow control valves 802 around over a selected interval can be closed in order to control the influx of formation fluids into the well bore 800. Conversely, all, or only a portion of the 802 flow control valves over a selected interval can be opened so controlling fluid injection at an interval.
[0185] [0185] Figures 9A and 9B demonstrate the isolation of selected subsurface areas using insulation column 810. Figures 9A and 9B generally copy Figures 7A and 7B, except that an insulation column 810 is positioned in the well holes at the instead of a transposition shutter or bridge plug. Insulation column 810 is secured from a closing seal device 142 and a polished hole receptacle (PBR) secured by production piping 130, while the upper base tube 205 of sand control devices 200 is secured to the well holes from a production plug 138 sealing the annular region to the coating column 106. The tubular junction 805 of the insulation column can be enlarged in diameter (shown in the area close to 145) before being connected to the production pipe 130. 802 flow control valves (not shown) can also be placed within the larger diameter pipe section (shown in the area close to 145) to increase the flow capacity of the upper isolated range 112.
[0186] [0186] First, Figure 9A is a cross-sectional view of a well hole 900A. The borehole of the well 900a is generally constructed according to the borehole of the well 100 of Figure 2. In addition, the borehole of the well 900A is generally constructed according to the borehole of the well 700A of Figure 7A. Therefore, details about the well bore 900A will not be repeated, except to note that an 810 insulation column was conducted in the base tubes 205 of the sand control devices 200. Also, portions of the filter medium or sand screen 207 are cut again to expose the 802 valves.
[0187] [0187] In Figure 9A, the well hole 900A is shown by cutting through a subsurface gap 114. The gap 114 represents an intermediate gap. This means that there is also an upper range 112 and a lower range 116 (seen in Figure 2, but not shown in Figure 9A).
[0188] [0188] As with the well hole 700A, the well hole 900A is constructed to isolate the intermediate range 114 from the 205 base tubes. To accomplish this, the flow control valves 802 along the intermediate range 114 have been closed. In addition, seals 804 have been fitted along the upper plug assembly 210 'and the lower plug assembly 210 ”. At the same time, flow control valves 802 remain open over the upper range 112 (partially shown) and the lower range 116 (not shown). In this way, the operator can continue to produce forming fluids (or inject fluids in) from the upper 112 and lower 116 ranges while sealing outside the intermediate range 114.
[0189] [0189] Second, Figure 9B is a cross-sectional view of a well hole 900B. The borehole of the well 900B is also generally constructed according to the borehole of the well 100 of Figure 2. In addition, the borehole of the well 900B is generally constructed according to the borehole of the well 700B of Figure 7B. Therefore, details about the well bore 900B will not be repeated, except to note that an 810 insulation column was conducted in the base tubes 205 of the sand control devices 200.
[0190] [0190] In Figure 9B, the well hole 900B is constructed to isolate the bottom gap 116 from the base tubes 205. The bottom gap 116 extends essentially to the bottom 136 of the well hole 900B and is the bottom zone of interest . To accomplish this, the flow control valves 802 over the lower range 116 have been closed. In addition, 804 seals were fitted along the 210 ”lower plug assembly. At the same time, flow control valves 802 remain open over the upper range 112 (not shown) and the intermediate range 114 (partially shown). In this way, the operator can continue to produce forming fluids (or inject fluids in) from the upper 112 and intermediate 114 ranges while sealing outside the lower 116 range.
[0191] [0191] It is observed for well holes 900A and 900B that, instead of completely stopping all valves 802 in the intermediate subsurface intervals 114 or less 116, the operator can alternatively choose to just close part of the valves associated with an interval. Alternatively, the operator may choose to only partially close some or all of the valves associated with an interval.
[0192] [0192] It is also observed for well holes 900A and 900B that direct openings or multiple flow ports are described for 802 valves. However, the flow control device associated with opening and closing 802 valves over a zone can be just one device, such that all the direct openings indicated by reference number 802 are technically one valve, or possibly just two valves.
[0193] [0193] Based on the above descriptions, a method for completing a borehole is provided here. The method is shown in Figure 10. Figure 10 provides a flow chart showing the steps for a 1000 method of completing a well bore, in various embodiments.
[0194] [0194] Method 1000 first includes providing a sand control device. This is shown in Box 1010. The sand control device may be according to the sand control devices 200 of Figure 2. In this regard, the sand control device generally includes an elongated base tube having at least two junctions, at least one alternating flow channel extending substantially along the base tube, and a filter means radially surrounding the base tube along a substantial portion of the base tube. In this way a sand screen is formed.
[0195] [0195] Method 1000 also includes providing a shutter assembly. This is provided in Box 1020. The plug assembly has at least one mechanically adjusted plug, such as the plug described in Ped. of Pat. Prov. No. 61 / 424,427, or an intumescible shutter. Thus, the plug usually has a sealing element, an internal mandrel, and at least one alternating flow channel in fluid communication with at least one alternating flow channel in the sand control device.
[0196] [0196] Method 1000 also includes connecting the plug assembly to the intermediate sand screen at least two joints. This is indicated in Box 1030. The method then includes conducting the plug and sand screen assembly connected to the well bore. This is provided in Box 1040. The plug and the connected sand screen are placed along the open hole portion (or other production interval) of the well hole.
[0197] [0197] Method 1000 also includes adjusting at least one mechanically adjusted shutter. This is seen in Box 1050. The step of adjusting Box 1050 is done by activating the sealing element of the plug in engagement with the open hole portion adjacent to the well hole. Then, method 1000 includes injecting a gravel slurry into an annular region formed between the sand screen and the open hole portion adjacent to the well hole, and then further injecting the gravel slurry through the alternating flow channels. This is shown in Box 1060.
[0198] [0198] Flow channels allow the gravel slurry to bypass the shutter. In this way, the open hole portion of the well hole is packed with gravel above and below the plug after the plug has been fitted to the well hole. Notably, the flow channels also allow the gravel slurry to bypass any premature sand bridges and the borehole areas collapse.
[0199] [0199] Flow channels can be circular bypass tubes located within a sand screen. Optionally, the flow channels can be rectangular bypass tubes eccentrically connected to the outside of a sand screen. An example of such a bypass tube arrangement is found on the Schlumberger’s OptiPac® sand screen. Where an external eccentric arrangement is used, a separate passage tool (not shown) would be required for connection to a concentric internal bypass open-hole plug.
[0200] [0200] In method 1000, it is preferred that the plug assembly also includes a mechanically adjusted secondary plug. The secondary mechanically adjusted shutter is constructed according to the primary mechanically adjusted shutter, or it can be substantially an identical image of it. An intumescible plug afterwards can be optionally supplied intermediate to the primary and secondary mechanically adjusted shutters. The swelling plug has alternating flow channels aligned with the alternating flow channels of the primary and secondary mechanically adjusted shutters. An example of an intumescent shutter arrangement is published in Publ. WIPO No. 06/06/2011 titled “Open-Hole Packer for Alternate Path Gravel Packing, and Method for Completing an Open-Hole Wellbore.” Alternatively, the plug assembly may include a zonal-based gravel-based insulation tool, meaning that the gravel is packaged around an elongated blank tube. An example of a gravel-based zonal isolation tool is described in Publ. of Pat. WO No. 2010/120419 entitled “Systems and Methods for Providing Zonal Isolation in Wells.”
[0201] [0201] In one aspect, each mechanically adjusted plug will have an inner mandrel, and alternating flow channels around the inner mandrel. The shutters can also have a movable piston housing and an elastomeric sealing element. The sealing element is operatively connected to the piston housing. This means that sliding the movable piston housing along each plug (in relation to the internal mandrel) will activate the respective sealing elements in engagement with the hole in the adjacent well.
[0202] [0202] Method 1000 may also include driving an adjustment tool on the internal mandrel of the obturators, and releasing the movable piston housing in each obturator from its fixed position. Preferably, the adjustment tool is part of or is conducted with a wash pipe used for packaging with gravel. The step of releasing the movable piston housing from its fixed position then comprises pulling the wash pipe with the adjustment tool along the internal mandrel of each plug. This serves to shear at least one shear pin and move the release sleeves in the respective shutters. Shearing the shear pin allows the piston housing to slide along the piston mandrel and exerts a force that adjusts the elastomeric plug elements.
[0203] [0203] Method 1000 also includes driving a pipe column into the well bore with an elongated insulation column connected to a lower end of the pipe column. This is shown in Box 1070 of Figure 10. The insulation column generally comprises a tubular body having an internal diameter defining a hole in fluid communication with a hole in the pipe column, and an outside diameter configured to reside within the base tube. of the sand control device and the mandrel of the shutter assembly. The isolation column also has a primary valve, and one or more seals along the outside diameter of the tubular body.
[0204] [0204] The primary valve can be a single direct opening. More preferably, the primary valve comprises a set of direct openings or flow ports provided over a selected subsurface interval. The valve can operate to fully open or only partially open the direct openings. Alternatively, the valve can operate to open some but not all direct openings over a selected range.
[0205] [0205] Method 1000 then includes placing the elongated insulation column inside the base tube of the sand control device, and through the plug assembly. This is seen in Box 1080 of Figure 10. Thus, the primary valve of the isolation column is above or below the plug assembly, and the seals of the insulation column are adjacent to the adjusted plug assembly.
[0206] [0206] The insulation column is preferably conducted with the production pipe column after the mechanically adjusted shutters have been adjusted, after the well has been packed with gravel, and after the wash pipe and attached adjustment tool have been pulled into the surface. Preferably, an open hole portion of the well hole is swept with a gravel packaging gel or the drilling mud is conditioned before the mechanically adjusted shutters are adjusted.
[0207] [0207] The insulation column is conducted in the well hole below a polished hole receptacle and a closing device. The polished bore receptacle is attached to the pipe column while leading into the well bore. The closing device is used to hold the polished hole receptacle in the position above a gravel packaging shutter and / or a production shutter, but it will have a shear characteristic. In addition, a shutter can be adjusted above the sand screens to isolate the annular space around the production pipe from the bottom well hole. A rack orientation sleeve can be located at the bottom of the insulation column to assist entry to the top of the sand control device.
[0208] [0208] Method 1000 also includes activating the seals in order to seal an annular region formed between the outer diameter of the tubular body and the adjacent mandrel adjacent to the adjusted plug assembly. This is provided in Box 1090. Activating the seals allows an operator to hydraulically isolate each of the multiple zones or combinations of zones from one another. The seals may be o-ring seals made from these. Alternatively, the seals can be an inflatable plug, a cup-type plug, a mechanical plug, or an intumescible plug. In one embodiment, six Viton / Teflon / Ryton (“VTR”) seal cells are wrapped around an 18 ”(45.72 cm) mandrel for a total length of 9 feet (2.74 m).
[0209] [0209] It is preferred that the primary valve comprises two or more direct openings through the tubular body. In this example, the method further includes closing at least one of the two or more direct openings, thereby restricting the flow of fluids through the tubular body. It is also preferred that the isolation column includes a secondary valve. In this example, the primary valve or the secondary valve is above the plug, and the other of the primary valve and the secondary valve is below the plug. In this example, the method further includes closing the primary valve, the secondary valve, or both, or alternatively opening the primary valve, the secondary valve, or both, thereby creating fluid communication between the selected valve and a bore in the base.
[0210] [0210] A common flow control uses slip sleeves operated by a displacement tool, power lines, or hydraulic lines. Optionally, a wireless array can be used, such as via acoustic signals or radio frequency identification (RFID) labels. Optionally, a pressure threshold system can be provided for the valves. For purposes of the present disclosure, the term "valve" includes direct openings or sliding sleeves operated by any of these means.
[0211] [0211] Benefits of the above method in its various embodiments include allocating production or injection between zones, blocking water / gas, selective stimulation, delayed production of selective zones, delayed injection in selective zones, or preventing or smoothing the flow crossed between the selected zones. When combined with measuring the multi-phase flow rate of the bottom of the well or other sensors of pressure, temperature, density, tracer, or bottom strength, subsurface control becomes more quantitative in analyzing production data .
[0212] [0212] It is observed that if any zone is intended to be a non-production zone or a non-injection zone, no valve or direct opening needs to be placed along such a zone. Instead, a blank section of the tube can be provided. The blank tube will be equipped with transport tubes as flow channels, but they do not need to have packaging tubes. In this example, the annular space of the well hole does not need to be packed with gravel over the isolated gap.
[0213] [0213] Method 1000 above can be used to selectively produce from or inject into multiple zones. This provides enhanced production control or subsurface injection at a multi-zone well completion.
[0214] [0214] Although it is evident that the inventions described here are well calculated to obtain the benefits and advantages presented above, it will be assessed that the inventions are susceptible to modification, variation and change without departing from the spirit of the latter. Improved methods for completing a borehole are provided in order to seal one or more selected subsurface intervals. An improved zone isolation device is also provided. The inventions allow an operator to produce fluids from or inject fluids over a selected subsurface range.

权利要求:
Claims (16)
[0001]
Method for completing an oil well (800) in a subsurface formation (112, 114, 116), characterized by the fact that it comprises: provide a sand control device (200) comprising: an elongated base tube (205) having at least two joints, at least one alternating flow channel extending substantially along the base tube (205), and a filter means (207) radially surrounding the base tube (205) along a substantial portion of the base tube (205) to form a sand screen; providing a plug assembly (210) comprising at least one mechanically adjusted plug (212, 214), each mechanically adjusted plug (212, 214) comprising: a sealing element, an internal mandrel (215), and at least one alternating flow channel; connect the plug assembly (210) to the intermediate sand screen to at least two junctions so that at least one alternating flow channel in the plug assembly (210) is in fluid communication with at least one alternating flow channel in the sand control device (200); driving the sand control device (200) and plugging assembly (210) connected to the oil well (800); adjust the at least one mechanically adjusted plug (212, 214) by activating the sealing element in engagement with the adjacent oil well; injecting a gravel slurry into the oil well (800) to form a gravel package above and below the plug assembly (210) after at least one mechanically adjusted plug has been adjusted (212,214); conduct a pipe column (130) in the oil well (800) with an elongated insulation column (810) connected at a lower end of the pipe column (130), the insulation column (810) comprising: a tubular body having an internal diameter defining a hole in fluid communication with a hole in the pipe column (130), and an external diameter configured to be received inside the base tube (205) and the internal mandrel (215), a first valve providing fluid communication between the bore of the tubular body and an annular region formed between the outer diameter of the tubular body and the adjacent base tube (205), and one or more seals (804) along the outside diameter of the tubular body; place the elongated insulation column (810) inside the base tube (205) and through the plug assembly (210) such that: the first valve is above or below the plug assembly (210), and one or more seals (804) are adjacent to the fitted shutter assembly (212, 214); and activating one or more seals (804) in order to seal an annular region formed between the outer diameter of the tubular body and the inner mandrel (215) that surrounds it adjacent to an adjusted plug (212, 214).
[0002]
Method according to claim 1, characterized in that the first valve comprises at least one direct opening through the tubular body, and the method further comprises: closing at least one of the at least one direct opening, thereby partially restricting the flow of fluids through the tubular body over a selected zone.
[0003]
Method according to claim 1, characterized in that closing at least one of the at least one direct opening is in response to (i) a mechanical force applied to the first valve, (ii) an electrical signal sent to the first valve, ( iii) an acoustic signal delivered to the first valve, (iv) the passing of a radio frequency identification (RFID) label through the first valve, or (v) hydraulic pressure supplied to the first valve.
[0004]
Method according to claim 1, characterized in that the isolation column (810) further comprises a second valve, and in which: the first valve or the second valve is above the plug (212,214); and the other from the first valve or the second valve is below the plug (212,214).
[0005]
Method according to claim 1, characterized in that each of the at least one mechanically adjusted plug (212, 214) further comprises: a movable piston housing retained around the inner mandrel (215); and one or more flow ports providing fluid communication between alternating flow channels and a pressure support surface of the piston housing.
[0006]
Method according to claim 5, characterized by the fact that it further comprises: driving an adjustment tool in the inner mandrel (215) of at least one mechanically adjusted plug before driving the elongated insulation column (810) in the sand control device (200); manipulate the adjustment tool to mechanically release the movable piston housing from its held position; and communicating hydrostatic pressure to the piston housing through one or more flow ports, thereby moving the released piston housing and activating the sealing element against the adjacent oil well.
[0007]
Method according to claim 6, characterized by the fact that it further comprises: driving an adjustment tool on the internal mandrel (215) of each of the primary and secondary shutters (214, 216) before driving the elongated insulation column (810) in the sand control device (200); manipulate the adjustment tool to mechanically release the movable piston housing from its retained position along each of the respective primary and secondary shutters (212, 214); and communicate hydrostatic pressure to the piston housings through one or more flow ports, thereby moving the released piston housings and activating the sealing element of each of the primary and secondary shutters (212, 214) against the oil well (800 ) adjacent.
[0008]
Method according to claim 1, characterized by the fact that the plug assembly (210) further comprises: a section of blank tube intermediate the primary mechanically adjusted plug (212) and the secondary mechanically adjusted plug (214); and place a pack with gravel around the blank tube section.
[0009]
Method according to claim 1, characterized by the fact that it further comprises: condition a column of drilling mud residing in the oil well (800) before driving the sand control device (200) and plug assembly (210) connected to the oil well (800).
[0010]
Method according to claim 1, characterized in that the isolation column (810) further comprises a second valve, and in which: the first valve is above the primary plug assembly (210); the second valve is intermediate to the primary and secondary plug assemblies (210); and the third valve is below the secondary plug assembly (210).
[0011]
Zonal insulation device for packaging with gravel, characterized by the fact that it comprises: a pipe column (130) comprising an internal hole for receiving fluids; a sand control device (200) comprising: an elongated base tube (205) extending from a primary end to a secondary end, at least one alternating flow channel along the base tube (205) extending from the primary end to the secondary end, and a filter means (207) radially surrounding the base tube (205) along a substantial portion of the base tube (205) to form a sand screen; a primary plug assembly (210) disposed along the sand control device (200), the plug assembly (210) comprising a mechanically adjusted upper plug (212) having: a sealing element, an internal mandrel (215), and at least one alternating flow channel in fluid communication with at least one alternating flow channel in the sand control device (200) to deflect the gravel packaging slurry in addition to the mechanically adjusted upper shutter during a packaging operation with gravel; and an elongated insulation column (810) passing through the plug assembly (210) and at least a portion of the sand control device (200), the insulation column (810) comprising: a tubular body having an internal diameter defining a hole in fluid communication with the pipe column (130), and an external diameter configured to be received inside the base tube (205) and the internal mandrel (215), a first valve above or below the plug assembly (210), the first valve defining at least one flow port that can be opened and closed in order to selectively place the hole in the tubular body in fluid communication with a hole in the pipe base (205), and one or more seals (804) along the outer diameter of the tubular body, one or more seals (804) being adjacent to the plug assembly (210) and sealing an annular region formed between the outer diameter of the tubular body and the inner mandrel ( 215) adjacent.
[0012]
Zone isolation device according to claim 11, characterized in that the first valve is configured to close at least one flow port in response to (i) a mechanical force applied to the first valve, (ii) an electrical signal sent to the first valve, (iii) an acoustic signal delivered to the first valve, (iv) the passing of a radio frequency identification (RFID) label through the first valve, or (v) hydraulic pressure supplied to the first valve.
[0013]
Zone isolation device according to claim 11, characterized in that the isolation column (810) further comprises a second valve, and in which: the first valve or the second valve is above the primary plug assembly (210); and the other from the first valve or the second valve is below the primary plug assembly (210).
[0014]
Zone isolation device according to claim 13, characterized by the fact that: each of the first valve and the second valve is configured so that at least one of the at least one flow port can be selectively closed, thereby partially restricting the flow of fluids through the tubular body.
[0015]
Zone isolation device according to claim 11, characterized in that the filter medium (207) for the sand screen comprises a wire-wrapped screen, a membrane screen, an expandable screen, a sintered metal screen, a wire mesh, a shape memory polymer, or a pre-packaged solid particle bed.
[0016]
Zone isolation device according to claim 11, characterized in that the shutter assembly further comprises: a mechanically adjusted lower shutter (214) also having: a sealing element, an internal mandrel (215), and at least one alternating flow channel in fluid communication with at least one alternating flow channel in the sand control device (200) to deflect the gravel packaging slurry in addition to the mechanically adjusted lower plug (214) during an operation packaging with gravel.

类似技术:

---

公开号 | 公开日 | 专利标题

---

BR112013013148B1|2020-07-21|well bore apparatus and methods for zonal isolation and flow control

---

AU2011341563B2|2016-05-12|Wellbore apparatus and methods for multi-zone well completion, production and injection

---

BR112013013146B1|2020-07-21|shutter for packing gravel in an alternative flow channel and method for completing a well

---

US8215406B2|2012-07-10|Wellbore method and apparatus for completion, production and injection

---

US8789612B2|2014-07-29|Open-hole packer for alternate path gravel packing, and method for completing an open-hole wellbore

---

BR112013013149B1|2020-10-06|CONNECTION JOINT FOR EXCENTRIC FLOW PATHWAYS TO CONCENTRIC FLOW PATHWAYS

---

US20170044880A1|2017-02-16|Hybrid Sand Control Systems and Methods for Completing a Wellbore with Sand Control

---

OA16454A|2015-10-15|Wellbore apparatus and methods for zonal isolation and flow control.

---

OA16313A|2015-04-24|Wellbore apparatus and methods for multizone well completion, production and injection.

---

OA16832A|2016-01-07|Crossover joint for connecting eccentric flow paths to concentric flow paths

---

OA16457A|2015-10-15|Packer for alternate flow channel gravel packing and method for completing a wellbore.

同族专利:

---

公开号 | 公开日

---

AU2011341452A1|2013-07-04|

---

CN103261573B|2016-06-22|

---

EA030438B1|2018-08-31|

---

BR112013013148A2|2016-08-23|

---

US9303485B2|2016-04-05|

---

CA2819627A1|2012-06-21|

---

MX338485B|2016-04-19|

---

WO2012082447A1|2012-06-21|

---

AU2011341452B2|2016-06-30|

---

CA2819627C|2016-10-18|

---

EA201390898A1|2014-04-30|

---

CN103261573A|2013-08-21|

---

EP2652246A4|2017-08-23|

---

US20130248178A1|2013-09-26|

---

SG190712A1|2013-07-31|

---

MY175095A|2020-06-05|

---

SG10201510415QA|2016-01-28|

---

EP2652246A1|2013-10-23|

---

MX2013006263A|2013-07-02|

引用文献:

---

公开号 | 申请日 | 公开日 | 申请人 | 专利标题

---

---

US4424859A|1981-11-04|1984-01-10|Sims Coleman W|Multi-channel fluid injection system|

---

CN2056938U|1989-05-08|1990-05-09|阳庆云|Take-down packer|

---

US4945991A|1989-08-23|1990-08-07|Mobile Oil Corporation|Method for gravel packing wells|

---

US5113935A|1991-05-01|1992-05-19|Mobil Oil Corporation|Gravel packing of wells|

---

US5377749A|1993-08-12|1995-01-03|Barbee; Phil|Apparatus for setting hydraulic packers and for placing a gravel pack in a downhole oil and gas well|

---

US5348091A|1993-08-16|1994-09-20|The Bob Fournet Company|Self-adjusting centralizer|

---

US5390966A|1993-10-22|1995-02-21|Mobil Oil Corporation|Single connector for shunt conduits on well tool|

---

US5396954A|1994-01-27|1995-03-14|Ctc International Corp.|Subsea inflatable packer system|

---

US5476143A|1994-04-28|1995-12-19|Nagaoka International Corporation|Well screen having slurry flow paths|

---

GB2290812B|1994-07-01|1998-04-15|Petroleum Eng Services|Release mechanism for down-hole tools|

---

US5588487A|1995-09-12|1996-12-31|Mobil Oil Corporation|Tool for blocking axial flow in gravel-packed well annulus|

---

US5887660A|1996-03-01|1999-03-30|Smith International, Inc|Liner packer assembly and method|

---

US6003834A|1996-07-17|1999-12-21|Camco International, Inc.|Fluid circulation apparatus|

---

US5868200A|1997-04-17|1999-02-09|Mobil Oil Corporation|Alternate-path well screen having protected shunt connection|

---

US5909774A|1997-09-22|1999-06-08|Halliburton Energy Services, Inc.|Synthetic oil-water emulsion drill-in fluid cleanup methods|

---

US5975205A|1997-09-30|1999-11-02|Carisella; James V.|Gravel pack apparatus and method|

---

EP0909875A3|1997-10-16|1999-10-27|Halliburton Energy Services, Inc.|Method of completing well in unconsolidated subterranean zone|

---

US6179056B1|1998-02-04|2001-01-30|Ypf International, Ltd.|Artificial lift, concentric tubing production system for wells and method of using same|

---

NO310585B1|1998-03-25|2001-07-23|Reslink As|Pipe connection for connection of double walled pipes|

---

RU2154150C2|1998-06-15|2000-08-10|Предприятие "Астраханьгазпром" РАО "Газпром"|Method of isolation of producing formation overlapped by flow string|

---

US6789623B2|1998-07-22|2004-09-14|Baker Hughes Incorporated|Method and apparatus for open hole gravel packing|

---

US6354378B1|1998-11-18|2002-03-12|Schlumberger Technology Corporation|Method and apparatus for formation isolation in a well|

---

US6405800B1|1999-01-21|2002-06-18|Osca, Inc.|Method and apparatus for controlling fluid flow in a well|

---

US6513599B1|1999-08-09|2003-02-04|Schlumberger Technology Corporation|Thru-tubing sand control method and apparatus|

---

US6789621B2|2000-08-03|2004-09-14|Schlumberger Technology Corporation|Intelligent well system and method|

---

US7222676B2|2000-12-07|2007-05-29|Schlumberger Technology Corporation|Well communication system|

---

US6409219B1|1999-11-12|2002-06-25|Baker Hughes Incorporated|Downhole screen with tubular bypass|

---

US6298916B1|1999-12-17|2001-10-09|Schlumberger Technology Corporation|Method and apparatus for controlling fluid flow in conduits|

---

AU782553B2|2000-01-05|2005-08-11|Baker Hughes Incorporated|Method of providing hydraulic/fiber conduits adjacent bottom hole assemblies for multi-step completions|

---

US6325144B1|2000-06-09|2001-12-04|Baker Hughes, Inc.|Inflatable packer with feed-thru conduits|

---

US6752206B2|2000-08-04|2004-06-22|Schlumberger Technology Corporation|Sand control method and apparatus|

---

US6997263B2|2000-08-31|2006-02-14|Halliburton Energy Services, Inc.|Multi zone isolation tool having fluid loss prevention capability and method for use of same|

---

AU9284701A|2000-09-20|2002-04-02|Sofitech Nv|Method for gravel packing open holes above fracturing pressure|

---

US6520254B2|2000-12-22|2003-02-18|Schlumberger Technology Corporation|Apparatus and method providing alternate fluid flowpath for gravel pack completion|

---

US6695067B2|2001-01-16|2004-02-24|Schlumberger Technology Corporation|Wellbore isolation technique|

---

US6557634B2|2001-03-06|2003-05-06|Halliburton Energy Services, Inc.|Apparatus and method for gravel packing an interval of a wellbore|

---

NO314005B1|2001-04-10|2003-01-13|Reslink As|Device for downhole cable protection|

---

US6575251B2|2001-06-13|2003-06-10|Schlumberger Technology Corporation|Gravel inflated isolation packer|

---

US6749023B2|2001-06-13|2004-06-15|Halliburton Energy Services, Inc.|Methods and apparatus for gravel packing, fracturing or frac packing wells|

---

US6516881B2|2001-06-27|2003-02-11|Halliburton Energy Services, Inc.|Apparatus and method for gravel packing an interval of a wellbore|

---

US6601646B2|2001-06-28|2003-08-05|Halliburton Energy Services, Inc.|Apparatus and method for sequentially packing an interval of a wellbore|

---

US6581689B2|2001-06-28|2003-06-24|Halliburton Energy Services, Inc.|Screen assembly and method for gravel packing an interval of a wellbore|

---

US6752207B2|2001-08-07|2004-06-22|Schlumberger Technology Corporation|Apparatus and method for alternate path system|

---

US6830104B2|2001-08-14|2004-12-14|Halliburton Energy Services, Inc.|Well shroud and sand control screen apparatus and completion method|

---

US7331388B2|2001-08-24|2008-02-19|Bj Services Company|Horizontal single trip system with rotating jetting tool|

---

US20040007829A1|2001-09-07|2004-01-15|Ross Colby M.|Downhole seal assembly and method for use of same|

---

US6644404B2|2001-10-17|2003-11-11|Halliburton Energy Services, Inc.|Method of progressively gravel packing a zone|

---

US6749024B2|2001-11-09|2004-06-15|Schlumberger Technology Corporation|Sand screen and method of filtering|

---

US7066284B2|2001-11-14|2006-06-27|Halliburton Energy Services, Inc.|Method and apparatus for a monodiameter wellbore, monodiameter casing, monobore, and/or monowell|

---

US6907936B2|2001-11-19|2005-06-21|Packers Plus Energy Services Inc.|Method and apparatus for wellbore fluid treatment|

---

US7661470B2|2001-12-20|2010-02-16|Baker Hughes Incorporated|Expandable packer with anchoring feature|

---

US7051805B2|2001-12-20|2006-05-30|Baker Hughes Incorporated|Expandable packer with anchoring feature|

---

US7096945B2|2002-01-25|2006-08-29|Halliburton Energy Services, Inc.|Sand control screen assembly and treatment method using the same|

---

US7207383B2|2002-02-25|2007-04-24|Schlumberger Technology Corporation|Multiple entrance shunt|

---

US20030173075A1|2002-03-15|2003-09-18|Dave Morvant|Knitted wire fines discriminator|

---

US6705402B2|2002-04-17|2004-03-16|Baker Hughes Incorporated|Gas separating intake for progressing cavity pumps|

---

DE10217182B4|2002-04-18|2009-05-07|Lurgi Zimmer Gmbh|Device for changing nozzles|

---

US6666274B2|2002-05-15|2003-12-23|Sunstone Corporation|Tubing containing electrical wiring insert|

---

US6789624B2|2002-05-31|2004-09-14|Halliburton Energy Services, Inc.|Apparatus and method for gravel packing an interval of a wellbore|

---

US7243715B2|2002-07-29|2007-07-17|Schlumberger Technology Corporation|Mesh screen apparatus and method of manufacture|

---

US7108067B2|2002-08-21|2006-09-19|Packers Plus Energy Services Inc.|Method and apparatus for wellbore fluid treatment|

---

NO318165B1|2002-08-26|2005-02-14|Reslink As|Well injection string, method of fluid injection and use of flow control device in injection string|

---

US7055598B2|2002-08-26|2006-06-06|Halliburton Energy Services, Inc.|Fluid flow control device and method for use of same|

---

US6935432B2|2002-09-20|2005-08-30|Halliburton Energy Services, Inc.|Method and apparatus for forming an annular barrier in a wellbore|

---

US6854522B2|2002-09-23|2005-02-15|Halliburton Energy Services, Inc.|Annular isolators for expandable tubulars in wellbores|

---

US6814139B2|2002-10-17|2004-11-09|Halliburton Energy Services, Inc.|Gravel packing apparatus having an integrated joint connection and method for use of same|

---

NO316288B1|2002-10-25|2004-01-05|Reslink As|Well packing for a pipe string and a method for passing a line past the well packing|

---

US6923262B2|2002-11-07|2005-08-02|Baker Hughes Incorporated|Alternate path auger screen|

---

NO318358B1|2002-12-10|2005-03-07|Rune Freyer|Device for cable entry in a swelling gasket|

---

US20040140089A1|2003-01-21|2004-07-22|Terje Gunneroed|Well screen with internal shunt tubes, exit nozzles and connectors with manifold|

---

US7048061B2|2003-02-21|2006-05-23|Weatherford/Lamb, Inc.|Screen assembly with flow through connectors|

---

EA007766B1|2003-02-26|2006-12-29|Эксонмобил Апстрим Рисерч Компани|Method for drilling and completing wells|

---

US6883608B2|2003-08-06|2005-04-26|Schlumberger Technology Corporation|Gravel packing method|

---

US20050028977A1|2003-08-06|2005-02-10|Ward Stephen L.|Alternate path gravel packing with enclosed shunt tubes|

---

US20050039917A1|2003-08-20|2005-02-24|Hailey Travis T.|Isolation packer inflated by a fluid filtered from a gravel laden slurry|

---

US7147054B2|2003-09-03|2006-12-12|Schlumberger Technology Corporation|Gravel packing a well|

---

US20050061501A1|2003-09-23|2005-03-24|Ward Stephen L.|Alternate path gravel packing with enclosed shunt tubes|

---

US7243732B2|2003-09-26|2007-07-17|Baker Hughes Incorporated|Zonal isolation using elastic memory foam|

---

US20050082060A1|2003-10-21|2005-04-21|Ward Stephen L.|Well screen primary tube gravel pack method|

---

US7347274B2|2004-01-27|2008-03-25|Schlumberger Technology Corporation|Annular barrier tool|

---

US7343983B2|2004-02-11|2008-03-18|Presssol Ltd.|Method and apparatus for isolating and testing zones during reverse circulation drilling|

---

US7866708B2|2004-03-09|2011-01-11|Schlumberger Technology Corporation|Joining tubular members|

---

US20050248334A1|2004-05-07|2005-11-10|Dagenais Pete C|System and method for monitoring erosion|

---

US20050263287A1|2004-05-26|2005-12-01|Schlumberger Technology Corporation|Flow Control in Conduits from Multiple Zones of a Well|

---

US7243723B2|2004-06-18|2007-07-17|Halliburton Energy Services, Inc.|System and method for fracturing and gravel packing a borehole|

---

US7597141B2|2004-06-23|2009-10-06|Weatherford/Lamb, Inc.|Flow nozzle assembly|

---

US7721801B2|2004-08-19|2010-05-25|Schlumberger Technology Corporation|Conveyance device and method of use in gravel pack operation|

---

US7367395B2|2004-09-22|2008-05-06|Halliburton Energy Services, Inc.|Sand control completion having smart well capability and method for use of same|

---

RU2368762C2|2005-01-14|2009-09-27|Бейкер Хьюз Инкорпорейтед|Bypass tube of device for inwashing gravel filter with attachment for control line and control line attachment method|

---

US7591321B2|2005-04-25|2009-09-22|Schlumberger Technology Corporation|Zonal isolation tools and methods of use|

---

US20090283279A1|2005-04-25|2009-11-19|Schlumberger Technology Corporation|Zonal isolation system|

---

US7870909B2|2005-06-09|2011-01-18|Schlumberger Technology Corporation|Deployable zonal isolation system|

---

US7497267B2|2005-06-16|2009-03-03|Weatherford/Lamb, Inc.|Shunt tube connector lock|

---

US7441605B2|2005-07-13|2008-10-28|Baker Hughes Incorporated|Optical sensor use in alternate path gravel packing with integral zonal isolation|

---

US7407007B2|2005-08-26|2008-08-05|Schlumberger Technology Corporation|System and method for isolating flow in a shunt tube|

---

US7431098B2|2006-01-05|2008-10-07|Schlumberger Technology Corporation|System and method for isolating a wellbore region|

---

CA2637040C|2006-02-03|2014-01-28|Exxonmobil Upstream Research Company|Wellbore system using shunt tubes|

---

GB2450648B|2006-03-23|2011-10-19|Petrowell Ltd|Improved packer|

---

CA2648024C|2006-04-03|2012-11-13|Exxonmobil Upstream Research Company|Wellbore method and apparatus for sand and inflow control during well operations|

---

US7562709B2|2006-09-19|2009-07-21|Schlumberger Technology Corporation|Gravel pack apparatus that includes a swellable element|

---

US7661476B2|2006-11-15|2010-02-16|Exxonmobil Upstream Research Company|Gravel packing methods|

---

US7938184B2|2006-11-15|2011-05-10|Exxonmobil Upstream Research Company|Wellbore method and apparatus for completion, production and injection|

---

US7631697B2|2006-11-29|2009-12-15|Schlumberger Technology Corporation|Oilfield apparatus comprising swellable elastomers having nanosensors therein and methods of using same in oilfield application|

---

US7637320B2|2006-12-18|2009-12-29|Schlumberger Technology Corporation|Differential filters for stopping water during oil production|

---

US7681652B2|2007-03-29|2010-03-23|Baker Hughes Incorporated|Packer setting device for high-hydrostatic applications|

---

US7918276B2|2007-06-20|2011-04-05|Schlumberger Technology Corporation|System and method for creating a gravel pack|

---

US7828056B2|2007-07-06|2010-11-09|Schlumberger Technology Corporation|Method and apparatus for connecting shunt tubes to sand screen assemblies|

---

US7775284B2|2007-09-28|2010-08-17|Halliburton Energy Services, Inc.|Apparatus for adjustably controlling the inflow of production fluids from a subterranean well|

---

GB0720420D0|2007-10-19|2007-11-28|Petrowell Ltd|Method and apparatus|

---

GB0723607D0|2007-12-03|2008-01-09|Petrowell Ltd|Improved centraliser|

---

US7832489B2|2007-12-19|2010-11-16|Schlumberger Technology Corporation|Methods and systems for completing a well with fluid tight lower completion|

---

US8127845B2|2007-12-19|2012-03-06|Schlumberger Technology Corporation|Methods and systems for completing multi-zone openhole formations|

---

US7624810B2|2007-12-21|2009-12-01|Schlumberger Technology Corporation|Ball dropping assembly and technique for use in a well|

---

US7735559B2|2008-04-21|2010-06-15|Schlumberger Technology Corporation|System and method to facilitate treatment and production in a wellbore|

---

US7784532B2|2008-10-22|2010-08-31|Halliburton Energy Services, Inc.|Shunt tube flowpaths extending through swellable packers|

---

GB2466475B|2008-11-11|2012-07-18|Swelltec Ltd|Wellbore apparatus and method|

---

US8347968B2|2009-01-14|2013-01-08|Schlumberger Technology Corporation|Single trip well completion system|

---

GB0901034D0|2009-01-22|2009-03-11|Petrowell Ltd|Apparatus and method|

---

US8453729B2|2009-04-02|2013-06-04|Key Energy Services, Llc|Hydraulic setting assembly|

---

SG10201401060UA|2009-04-14|2014-05-29|Exxonmobil Upstream Res Co|Systems and methods for providing zonal isolation in wells|WO2011062669A2|2009-11-20|2011-05-26|Exxonmobil Upstream Research Company|Open-hole packer for alternate path gravel packing, and method for completing an open-hole wellbore|

---

AU2011341563B2|2010-12-17|2016-05-12|Exxonmobil Upstream Research Company|Wellbore apparatus and methods for multi-zone well completion, production and injection|

---

EP2825728A2|2012-03-15|2015-01-21|Chevron U.S.A., Inc.|Outward venting of inflow tracer in production wells|

---

US9284815B2|2012-10-09|2016-03-15|Schlumberger Technology Corporation|Flow restrictor for use in a service tool|

---

GB2508710B|2012-10-16|2015-05-27|Petrowell Ltd|Flow control assembly|

---

WO2014066071A1|2012-10-26|2014-05-01|Exxonmobil Upstream Research Company|Downhole flow control, joint assembly and method|

---

US9187995B2|2012-11-08|2015-11-17|Baker Hughes Incorporated|Production enhancement method for fractured wellbores|

---

US10082000B2|2012-12-27|2018-09-25|Exxonmobil Upstream Research Company|Apparatus and method for isolating fluid flow in an open hole completion|

---

CN103993870A|2013-02-19|2014-08-20|大庆国电海天科技有限公司|Layer-by-layer detection method for parameters under oil field oil-water well|

---

WO2015017638A1|2013-07-31|2015-02-05|Schlumberger Canada Limited|Sand control system and methodology|

---

US9816361B2|2013-09-16|2017-11-14|Exxonmobil Upstream Research Company|Downhole sand control assembly with flow control, and method for completing a wellbore|

---

GB2522272A|2014-01-21|2015-07-22|Tendeka As|Downhole flow control device and method|

---

US9551216B2|2014-05-23|2017-01-24|Baker Hughes Incorporated|Packer element with laminar fluid entry|

---

US20170044880A1|2015-08-10|2017-02-16|Charles S. Yeh|Hybrid Sand Control Systems and Methods for Completing a Wellbore with Sand Control|

---

US10563486B2|2016-06-06|2020-02-18|Baker Hughes, A Ge Company, Llc|Screen assembly for a resource exploration system|

---

US10450843B2|2016-06-06|2019-10-22|Baker Hughes, A Ge Company, Llc|Screen assembly for a resource exploration system|

---

US10544648B2|2017-04-12|2020-01-28|Saudi Arabian Oil Company|Systems and methods for sealing a wellbore|

---

US10947823B2|2017-08-03|2021-03-16|Halliburton Energy Services, Inc.|Erosive slurry diverter|

---

US10669810B2|2018-06-11|2020-06-02|Saudi Arabian Oil Company|Controlling water inflow in a wellbore|

---

RU2726665C1|2019-11-29|2020-07-15|Публичное акционерное общество "Татнефть" имени В.Д. Шашина|Method of horizontal borehole attachment|

---

CN111119789A|2019-12-30|2020-05-08|河南工程学院|Well completion method for coal bed gas ground L-shaped pre-pumping well with double-well-opening structure|

法律状态:
2018-12-18| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|

---

2019-08-20| B06U| Preliminary requirement: requests with searches performed by other patent offices: procedure suspended [chapter 6.21 patent gazette]|

---

2020-02-11| B06A| Patent application procedure suspended [chapter 6.1 patent gazette]|

---

2020-05-19| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|

---

2020-07-21| B16A| Patent or certificate of addition of invention granted [chapter 16.1 patent gazette]|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 06/12/2011, OBSERVADAS AS CONDICOES LEGAIS. |

优先权:

---

申请号 | 申请日 | 专利标题

---

US201061424427P| true| 2010-12-17|2010-12-17|

---

US61/424,427|2010-12-17|

---

US201161482788P| true| 2011-05-05|2011-05-05|

---

US61/482,788|2011-05-05|

---

US201161561116P| true| 2011-11-17|2011-11-17|

---

US61/561,116|2011-11-17|

---

PCT/US2011/063356|WO2012082447A1|2010-12-17|2011-12-06|Wellbore apparatus and methods for zonal isolation and flow control|

---