shutter for packing gravel in an alternative flow channel and method for completing a well

专利摘要:
SHUTTER FOR PACKAGING GRAVEL IN ALTERNATIVE FLOW CHANNEL AND METHOD FOR COMPLETING A WELL. Apparatus and method for completing a well, including providing a plug having an inner mandrel, alternative flow channels along the inner mandrel, and a sealing element external to the inner mandrel, including connecting the plug to the tubular body, then inserting the plug. plug and tubular body connected inside the well. In one aspect, the plug and connected tubular body can be placed along a hole-open part of the well. The tubular body may be a sand sieve, with the sand sieve comprising a base tube, a surrounding filter medium, and alternative flow channels. The method includes placing a plug and injecting a gravel sludge into an annular region formed between the tubular body and the surrounding well, and then injecting the gravel sludge through the alternative flow channels, to allow the gravel sludge through least partially deflect the sealing element from the plug.
公开号:BR112013013146B1
申请号:R112013013146-2
申请日:2011-11-17
公开日:2020-07-21
发明作者:Charles S. Yeh；Michael D. Barry；Michael T. Hecker；Tracy J. Moffett；Jon Blacklock；David C. Haeberle；Patrick C. Hyde；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. BACKGROUND OF THE INVENTION
[0002] [0002] This section is intended to introduce various aspects of the art, which can be associated with exemplary embodiments of the present description. This discussion is believed to assist in providing a structure to facilitate a better understanding of particular aspects of the present description. Therefore, it should be understood that this section should be read in this light and not necessarily as admissions to the prior art. FIELD OF THE INVENTION
[0003] [0003] The present description refers to the well completion field. More specifically, the present invention relates to the isolation of well-related formations that have been completed using gravel packaging. The order also relates to a downhole plug, which can be placed inside a jacketed hole or an open hole and incorporates Alternate Path® Technology. TECHNOLOGY DISCUSSION
[0004] [0004] When drilling oil and gas wells, a well is formed using a drill bit that is pressed downward on a lower end of a drilling column. After drilling at a predetermined depth, the drill column and drill are removed and the well is lined with a column of casing tubes. An annular area is thus formed between the column of casing tubes and the formation. A cementation operation is typically conducted in order to fill or “press” the annular area with cement. The combination of cement and casing tubes strengthens the well and facilitates the isolation of the formation behind the casing tubes.
[0005] [0005] It is common to place several columns of coating tubes, progressively having smaller outside diameters, inside the well. The process of drilling and then cementing progressively smaller columns of casing tubes is repeated several times until the well has reached full depth. The column of final lining tubes, referred to as the production lining, is cemented into position and drilled. In some instances, the column of liner tubes is a liner, that is, a column of liner tubes that is not tied 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 with the surface, or the injection of fluids into the well. Fluid collection and processing equipment, such as tubes, valves and separators, are also provided. Production operations can then begin.
[0007] [0007] It is sometimes desirable to leave the base part of a well open. In open-hole completions, a production liner is not extended through the production zones and drilled; more precisely, the producing zones are left uncoated, or “open”. A production column or “pipe” is then positioned inside the well, extending below the last column of casing tubes and through a subsurface formation.
[0008] [0008] There are certain advantages to open hole completion versus hole-lined completion. First, because the open-hole completions do not have drilling tunnels, the formation fluids can converge over the well radially 360 degrees. This has the benefit of eliminating the additional pressure drop associated with converging radial flow and then linear flow through the particle-filled drilling tunnels. The reduced pressure drop, associated with an open-hole completion, virtually guarantees that it will be more productive than a coated, unstimulated hole of the same formation.
[0009] [0009] Second, open-hole techniques are often less expensive than jacketed hole completions. For example, the use of gravel packs eliminates the need for cementation, drilling and post-drilling cleaning operations.
[0010] [0010] A common problem in open-hole completion is the immediate exposure of the well to the surrounding formation. If the formation is not consolidated or intensely sandy, the flow of production fluids into the well can carry particles from the formation with it, for example, sand and fines. Such particles can be erosive for downhole production equipment and for pipes, valves and surface separation equipment.
[0011] [0011] To control the invasion of sand and other particles, sand control devices can be used. Sand control devices are generally installed at the bottom of wells 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 slit openings. The base tube is then typically enclosed with a filtering medium, such as a sieve or wire mesh.
[0012] [0012] To increase sand control devices, particularly in open-hole completions, it is common to install a gravel package. Packing gravel from a well involves placing gravel or other particulate material around the sand control device after the sand control device is suspended or otherwise placed inside the well. To install a gravel package, a particulate material is supplied to the bottom of the well through a conveyor fluid. The carrier fluid with the gravel together forms a gravel sludge. The mud dries in position, leaving a circumferential packing of gravel. The gravel not only helps in filtering particles, but also helps to maintain the integrity of the formation.
[0013] [0013] In a completed hole-open gravel package, the gravel is positioned between a sand sieve, which surrounds a perforated base tube and a wall surrounding the well. During production, fluid formation flows from the underground formation, through the gravel, through the sieve and into the inner base tube. The base tube thus serves as a part of the production column.
[0014] [0014] A problem historically encountered with gravel packing is that an inadvertent loss of slurry-carrying fluid during the supply process can result in the premature formation of sand or gravel bridges at various locations throughout the open-hole intervals. For example, in an inclined production interval or an interval having an enlarged or irregular borehole, poor gravel distribution can occur due to premature loss of transport fluid from the gravel sludge into the formation. The formation of a premature sand bridge can block the flow of the gravel sludge, causing the formation of voids along the completion interval. Thus, a complete gravel package from the base to the top is not achieved, leaving the well exposed to sand and fines infiltration.
[0015] [0015] Sand bridge formation problems have been addressed through the use of Alternate Path® Technology, or “APT”. Alternate Path® Technology employs bypass tubes (or bypasses) that allow the gravel sludge to deviate from selected areas along a well. Such alternative path technology is described, for example, in U.S. Pat. No. 5,588,487, entitled "Tool for Blocking Axial Flow in Gravel-Packed Well Annulus," and Pat. No. 7,938,184, entitled "Welbore Method and Apparatus for Completion, Production, and Injection". Additional references that discuss bypass technology include Pat. No. 4,945,991; Pat. No. 5,113,935; Pat. No. 7,661,476; and M.D. Barry, et al., “Open-hole Gravel Packing with Zonal Isolation,” SPE Paper No. 110,460 (November 2007).
[0016] [0016] The effectiveness of a gravel package in controlling the inflow of sand and fines into a well is well known. However, it is also sometimes desirable in open hole completions, to isolate selected intervals along the open hole part of a well in order to control the inflow of fluids. For example, with respect to the production of condensable hydrocarbons, water can sometimes invade an interval. This may be due to the presence of areas of native water, formation of cones (increased hydrocarbon-water contact near the well), high permeability veins, natural fractures, or infiltration of injection wells. Depending on the mechanism or cause of water production, water can be produced at different locations and occasions during the life of the well. Similarly, a gas cap above a gas reservoir can expand and advance, causing oil to produce gas. The gas advance reduces the activation of the gas cap and suppresses oil production.
[0017] [0017] In these and other examples, it is desirable to isolate the interval of production of the formation fluids into the well. Zonal annular isolation may also be desired for production allocation, production / injection fluid profile control, selective stimulation, or water or gas control. However, the design and installation of open-hole shutters is slightly problematic, due to flooded areas, undermining 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 cone formation often increases later in the life of a field, due to lowering and depleting pressure. Therefore, there is a need for an improved sand control system, which provides diversion technology for placing gravel that deviates from a shutter. There is still a need for a filling unit that provides isolation from selected subsurface intervals along an open-hole well. In addition, there is a need for a plug that uses alternative flow channels and provides a hydraulic seal to a borehole well before any gravel is placed around the sealing element. SUMMARY OF THE INVENTION
[0018] [0018] A specially designed downhole shutter is first offered here. The downhole plug can be used to seal an annular region between a tubular body and a surrounding open-hole well. The downhole plug can be placed along a column of sand control devices, and adjusted before a gravel packing operation begins.
[0019] [0019] In one embodiment, the downhole plug comprises an internal mandrel. The internal mandrel defines an elongated tubular body. In addition, the downhole plug has at least one alternative flow channel along the inner mandrel. In addition, the downhole plug has a sealing element external to the internal mandrel. The sealing element resides circumferentially around the inner mandrel.
[0020] [0020] The downhole plug still includes a movable piston enclosure. The piston housing is initially retained around the inner mandrel. The piston housing has a pressure bearing surface at a first end and is operatively connected to the sealing element. The piston housing can be released and moved along the inner mandrel. The movement of the piston enclosure drives the sealing element into the socket with the surrounding open borehole.
[0021] [0021] Preferably, the downhole plug still includes a piston mandrel. The piston mandrel is arranged between the inner mandrel and the surrounding piston enclosure. An annular crown is preserved between the inner mandrel and the piston mandrel. The annular crown usefully serves as the at least one alternative flow channel through the plug.
[0022] [0022] The downhole plug can also include one or more holes. The flow holes provide fluid communication between the alternate flow channel and the pressure bearing surface of the piston enclosure. The flow holes are sensitive to hydrostatic pressure inside the well.
[0023] [0023] In one embodiment, the downhole shutter also includes a release sleeve. The release sleeve resides along an inner surface of the inner mandrel. In addition, the downhole shutter includes a release key. The release switch is connected to the release sleeve. The release key is movable between a holding position, in which the release key engages and holds the movable piston housing in position, and a release position, in which the release key disengages from the piston housing. When disengaged, an absolute pressure acts against the pressure bearing surface of the piston housing and moves the piston housing to activate the sealing element.
[0024] [0024] In one aspect, the downhole plug also has at least one shear pin. The at least one shear pin can be one or more retaining screws. The shear pin or pins reliably connect the release sleeve to the release key. The shear pin or pins are sheared when a placement tool is pulled over the inner mandrel and the release sleeve slides.
[0025] [0025] In one embodiment, the downhole shutter also has a centralizer. The centralizer may be operable in response to manipulation of the shutter or sealing mechanism or, in other embodiments, be operable separately from manipulation of the shutter or sealing mechanism.
[0026] [0026] A method for completing a well is also provided here. The well may include a bottom part completed as an open-hole. In one aspect, the method includes providing a shutter. The shutter can be according to the shutter described above. For example, the plug will have an internal mandrel, alternative flow channels around the internal mandrel, and a sealing element external to the internal mandrel. The sealing member is preferably an elastomeric cup-like member.
[0027] [0027] The method also includes connecting the plug to a tubular body, and then inserting the plug and connected tubular body into the well. The plug and tubular body connected are placed along the hole-open part of the well. Preferably, the tubular body is a sand sieve, with the sand sieve comprising a base tube, a surrounding filter medium, and alternative flow channels. Alternatively, the tubular body may be a blank tube comprising alternative flow channels. Alternative flow channels can be internal or external to the filter medium or to the blank tube, as the case may be.
[0028] [0028] The base tube of the sand sieve can be composed of a plurality of joints. For example, the plug can be connected between two of the plurality of joints of the base tube.
[0029] [0029] The method also includes placing the shutter. This is done by activating the sealing element of the plug in the socket with the hole-open part surrounding the well. As an alternative, the plug can be placed along a non-perforated joint of casing tubes. Next, the method includes injecting a gravel sludge into an annular region formed between the tubular body and the surrounding well, and then injecting the gravel sludge through alternative flow channels to allow the gravel sludge to deviate of the sealing element. In this way, the open-hole part of the well is packed with gravel below the plug. In one aspect, the well is packed with gravel above and below the obturator, after the obturator has been completely placed in the borehole.
[0030] [0030] In one embodiment here, the obturator is a first mechanically placed obturator that is part of a obturator unit. In this example, the obturator unit can comprise a second obturator mechanically placed according to the first obturator. The step of injecting gravel sludge through alternative flow channels allows the gravel sludge to bypass the sealing element of the filling unit, so that the hole-open part of the well is packed with gravel above and below the filling unit, after the first and second mechanically placed shutters have been adjusted in the well.
[0031] [0031] The method may also include introducing a placement tool into the internal mandrel of the plug, and releasing the movable piston enclosure from its retained position. The method then includes transmitting hydrostatic pressure to the piston enclosure through one or more flow holes. Transmitting hydrostatic pressure moves the released piston enclosure and activates the sealing element against the surrounding well.
[0032] [0032] It is preferred that the laying tool is part of a washing tube used for packing gravel. In this example, introducing the placement tool comprises introducing a wash tube into a well inside the inner mandrel of the plug, with the wash tube having a placement tool on it. The step of releasing the movable piston enclosure from this retained position then comprises pulling the wash tube with the placement tool along the internal mandrel. The release sleeve moves to shear at least one shear pin and displace the release sleeve. This still serves to release at least one release key, and to release the piston housing.
[0033] [0033] The method may also include producing hydrocarbon fluids of at least one gap along the open-hole part of the well. BRIEF DESCRIPTION OF THE DRAWINGS
[0034] [0034] So that the way in which the present inventions can be better understood, certain illustrations, diagrams and / or flowcharts are attached here. It should be noted, however, that the drawings illustrate only selected embodiments of the inventions and are therefore not to be considered as limiting the scope, since the inventions may admit other equally effective embodiments and applications.
[0035] [0035] Figure 1 is a cross-sectional view of an illustrative well. The well was drilled through three different subsurface intervals, each interval being under pressure from the formation and containing fluids.
[0036] [0036] Figure 2 is an enlarged cross-sectional view of an open-hole completion of the well in Figure 1. The open-hole completion at the depth of the three illustrative intervals is most clearly seen.
[0037] [0037] Figure 3A is a cross-sectional side view of a filling unit, in one embodiment. Here, a base tube is shown, with surrounding plug elements. Two mechanically placed shutters are shown in relation to each other.
[0038] [0038] Figure 3B is a cross-sectional view of the filling unit in Figure 3A, taken through lines 3B-3B in Figure 3A. The bypass tubes are seen inside the filling unit.
[0039] [0039] Figure 3C is a cross-sectional view of the filling unit of Figure 3A, in an alternative embodiment. Instead of bypass tubes, the transport tubes are seen distributed around the base tube.
[0040] [0040] Figure 4A is a side view in cross section of the filling unit of Figure 3A. Here, sand control devices, or sand sieves, were placed at opposite ends of the filling unit. The sand control devices use external bypass tubes.
[0041] [0041] Figure 4B provides a cross-sectional view of the filling unit of Figure 4A, taken through lines 4B-4B of Figure 4A. The bypass tubes are seen outside the sand sieve, providing an alternative flow path for particulate sludge.
[0042] [0042] Figure 5A is another side view in cross section of the filling unit of Figure 3A. Here, the sand control devices, or sand sieves, were again placed at opposite ends of the filling unit. However, sand control devices use internal bypass tubes.
[0043] [0043] Figure 5B provides a cross-sectional view of the filling unit of Figure 5A, taken through lines 5B-5B of Figure 5A. The bypass tubes are seen inside the sand sieve to provide an alternative flow path for a particulate sludge.
[0044] [0044] Figure 6A is a side view in cross section of one of the mechanically placed shutters in Figure 3A. The mechanically placed plug is in its insertion position.
[0045] [0045] Figure 6B is a side view in cross section of the mechanically placed plug of Figure 3A. Here, the mechanically placed plug element is in its placed position.
[0046] [0046] Figure 6C is a cross-sectional view of the mechanically placed plug of Figure 6A. The view is taken through line 6C-6C in Figure 6A.
[0047] [0047] Figure 6D is a cross-sectional view of the mechanically placed plug of Figure 6A. The view is taken through line 6D-6D of Figure 6B.
[0048] [0048] Figure 6E is a cross-sectional view of the mechanically placed plug of Figure 6A. The view is taken through line 6E-6E of Figure 6A.
[0049] [0049] Figure 6F is a cross-sectional view of the mechanically placed plug of Figure 6A. The view is taken through line 6F-6F in Figure 6B.
[0050] [0050] Figure 7A is an enlarged view of the release key in Figure 6A. The release key is in its insertion position along the internal mandrel. The shear pin has not yet been sheared.
[0051] [0051] Figure 7B is an enlarged view of the release key in Figure 6B. The shear pin was sheared, and the release key fell away from the inner mandrel.
[0052] [0052] Figure 7C is a perspective view of a placement tool, which can be used to attach to a release sleeve and thereby shear a shear pin into the release key.
[0053] [0053] Figures 8A to 8J show stages of a gravel packing procedure, employing one of the filling units of the present invention, in one embodiment. The alternative flow path channels are provided through the filling elements of the filling unit and through the sand control devices.
[0054] [0054] Figure 8K shows the filling unit and gravel package having been placed in an open-hole well following the completion of the gravel packing procedure of Figures 8A to 8N.
[0055] [0055] Figure 9A is a cross-sectional view of an intermediate interval of the hole-open completion of Figure 2. Here, a straddle plug was placed inside a sand control device through the intermediate interval, to avoid the inflow. of training fluids.
[0056] [0056] Figure 9B is a cross-sectional view of the intermediate and lower intervals of the open-hole completion of Figure 2. Here, a plug was placed inside a filling unit between the intermediate and lower intervals, to prevent the flow of formation fluids up the well from the lower range.
[0057] [0057] Figure 10 is a flowchart showing steps that can be taken in relation to a method for completing an open-hole well, in one embodiment.
[0058] [0058] Figure 11 is a flow chart that provides steps for a method of placing a shutter, in an embodiment. The plug is placed in an open-hole well, and includes alternative flow channels. DETAILED DESCRIPTION OF CERTAIN WAYS OF ACCOMPLISHMENT
[0059] [0059] Definitions
[0060] [0060] 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, and cyclic, or closed-chain hydrocarbons, including cyclic terpenes. Examples of hydrocarbon-containing materials include any form of natural gas, oil, coal and bitumen, which can be used as a fuel or improved in a fuel.
[0061] [0061] As used herein, 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 bed methane, shale oil, pyrolysis oil, pyrolysis gas, a coal pyrolysis product, and other hydrocarbons that are in a gaseous or liquid state .
[0062] [0062] As used herein, 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.
[0063] [0063] As used here, the term "subsurface" refers to geological strata occurring below the earth's surface.
[0064] [0064] The term "subsurface gap" refers to a formation or a part of a formation in which the formation fluids may reside. The fluids can be, for example, hydrocarbon liquids, hydrocarbon gases, aqueous fluids, or combinations thereof.
[0065] [0065] As used here, the term “well” (wellbore) refers to a hole in the subsurface made by drilling or inserting a conduit inside the subsurface. A wellbore can have a substantially circular cross-section, or other cross-sectional shape. As used here, the term “well” (well), when referring to an opening in the formation, can be used interchangeably with the term “well” (wellbore).
[0066] [0066] The term "tubular member" refers to any tube, such as a joint of casing tubes, a part of a lining, or a joint joint.
[0067] [0067] The term "sand control device" means any elongated tubular body, which allows an influx of fluid into an internal hole or a base tube, while filtering predetermined sizes of sand, fine and granular debris from a formation surrounding.
[0068] [0068] The term "alternative flow channels" means any collection of distribution tubes and / or bypass tubes that provide fluid communication through or around a downhole tool, such as a plug, to allow the mud deviates from the shutter, or any premature sand bridge from an annular region, and proceed to packing gravel below, or above and below, the tool. DESCRIPTION OF THE SPECIFIC ACHIEVEMENTS.
[0069] [0069] The inventions are described here in connection with certain specific embodiments. However, to the extent that the following detailed description is specific to a particular embodiment or a particular use, it is intended to be illustrative only and is not to be construed as limiting the scope of the inventions.
[0070] [0070] Certain aspects of the inventions are also described in connection with various figures. In certain figures, the top of the drawing page is intended to be towards the surface and the base of the drawing page towards the bottom of the well. Although the wells are generally completed in substantially vertical orientation, it is understood that the wells can also be tilted and or even horizontally completed. When the descriptive terms “top and bottom” or “top” and “bottom” or similar terms are used with reference to a drawing or in the claims, they are intended to indicate the relative location on the drawing page or with respect to the claim terms and not necessarily orientation on the ground, since the present inventions are useful, no matter how the well is oriented.
[0071] [0071] Figure 1 is a cross-sectional view of an illustrative well 100. Well 100 defines a hole 105 that extends from a surface 101 and into the subsurface of the earth 110. Well 100 is completed to have a portion open bore 120 at a lower end of well 100. Well 100 was formed for the purpose of producing hydrocarbons for commercial sale. A production pipeline column is provided at bore 105 to transport production fluids from the open-hole part 120 to surface 101.
[0072] [0072] Well 100 includes a well tree, shown schematically in 124. Well tree 124 includes a shut-off valve 126. The shut-off valve controls the flow of production fluids from well 100. In addition, a shut-off valve subsurface safety 132 is provided to block the flow of fluids from production line 130 in the event of a rupture or catastrophic event above the subsurface safety valve 132. Well 100 can optionally have a pump (not shown) inside or just above from the borehole part 120 to artificially lift production fluids from the borehole part 120 to the shaft tree 124.
[0073] [0073] Well 100 has been completed by placing a series of tubes within subsurface 110. These tubes include a first column of casing tubes 102, sometimes known as surface casing tubes or a conductor. These tubes also include at least a second 104 and a third 106 column of casing tubes. These lining tube columns 104, 106 are intermediate lining tube columns that provide support for the walls of the well 100. The intermediate lining tube columns 104, 106 can be suspended from the surface, or can be suspended by a next column. of higher lining tubes, employing an expandable liner or liner hanger. It should be understood that a column of tubes that does not extend to the surface again (such as a column of casing tubes 106) is commonly referred to as a "liner".
[0074] [0074] In the illustrative well arrangement of Figure 1, the column of intermediate lining tubes 104 is suspended by surface 101, while the column of lining tubes 106 is suspended from a lower end of the column of lining tubes 104. The columns additional intermediate liner tubes (not shown) can be employed. The present inventions are not limited to the type of casing arrangement used.
[0075] [0075] Each column of casing tubes 102, 104, 106 is placed in position through cement 108. Cement 108 isolates the various formations of subsurface 110 of well 100 and between them. The cement 108 extends from the surface 101 to a depth "L" at a lower end of the column of liner tubes 106. It should be understood that some columns of intermediate liner tubes may not be fully cemented.
[0076] [0076] An annular region 204 is formed between the production pipe 130 and the column of casing tubes 106. A production plug 206 seals the annular region 204 near the lower end "L" of the column of casing tubes 106.
[0077] [0077] In many wells, a column of final lining tubes, known as production lining tubes, is cemented into position at a depth where the subsurface production intervals reside. However, illustrative well 100 is completed as an open-hole well. Therefore, well 100 does not include a column of final liner tubes along open hole portion 120.
[0078] [0078] In the illustrative well 100, the open-hole part 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 lower range 116 may, for example, contain valuable oil deposits that are sought to be produced, while the intermediate range 114 may contain mainly water or another aqueous fluid within its porous volume. This may be due to the presence of areas of native water, streaks of high permeability or natural fractures in the aquifer, or infiltration of injection wells. In this example, there is a likelihood that water will invade well 100.
[0079] [0079] Alternatively, the upper 112 and intermediate 114 ranges may contain hydrocarbon fluids that are sought to be produced, processed and sold, while the lower range 116 may contain some oil along with ever-increasing amounts of water. This may be due to the formation of cones, which is an elevation of water-hydrocarbon contact near the well. In this example, there is again the possibility that water will invade well 100.
[0080] Alternatively, the upper 112 and lower 116 ranges may be producing hydrocarbon fluids from a matrix of sand or other permeable rock, while the intermediate range 114 may represent a non-permeable or otherwise substantially fluid impervious shale.
[0081] [0081] In any of these events, it is desirable for the operator to isolate the 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 well 100 and surface 101. In the second example, the operator eventually he will want to isolate the lower range 116 of the production column 130 and the upper ranges 112 and intermediate 114, so that mainly hydrocarbon fluids can be produced through well 100 and to surface 101. In the third example, the operator will want to isolate the range upper 112 of the lower interval 116, however, it will not be necessary to isolate the intermediate interval 114. Solutions to these needs, in the context of an open-hole completion, are provided here, and are demonstrated more fully with respect to the drawings coming from.
[0082] [0082] Regarding the production of hydrocarbon fluids from a well 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 avoid the migration of particles from the formation into the production column 130 during operation, sand control devices 200 have been introduced in well 100. These are described more fully below with reference to Figure 2 and Figures 8A to 8J .
[0083] [0083] 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 joint making up the base tube 205) typically has smaller perforations or slits to allow the influx of production fluids.
[0084] [0084] Sand control devices 200 also contain filter media 207 wrapped or otherwise placed radially around base tubes 205. Filter media 207 may be a wire mesh sieve or embedded wire winding. around the base tube 205. The filter medium 207 prevents the influx of sand or other particles over a predetermined size into the base tube 205 and the production pipe 130.
[0085] [0085] In addition to the sand control devices 200, well 100 includes one or more filling units 210. In the illustrative arrangement of Figures 1 and 2, well 100 has an upper filling unit 210 'and a lower filling unit 210 ”. However, additional filling units 210 or just one filling unit 210 can be used. The shutter units 210 ’, 210 ″ are uniquely configured to seal an annular region (see e, 202 of Figure 2) between the various sand control devices 200 and a surrounding wall 201 of the open-hole part 120 of the well 100.
[0086] [0086] Figure 2 is an enlarged cross-sectional view of the borehole part 120 of well 100 of Figure 1. The borehole part 120 and the three intervals 112, 114, 116 are most clearly seen. The upper 210 'and lower 210' shutter units are also more clearly visible near the upper and lower limits of the intermediate range 114, respectively. Finally, the sand control devices 200 along each of the intervals 112, 114, 116 are shown.
[0087] [0087] With respect to the filling units themselves, each filling unit 210 ’, 210” can have at least two shutters. The shutters are preferably placed through a combination of mechanical manipulation and hydraulic forces. The plug units 210 represent an upper plug 212 and a lower plug 214. Each plug 212, 214 has an expandable part or element made of an elastomeric or thermoplastic material capable of providing at least a temporary fluid seal against the surrounding well wall 201 .
[0088] [0088] The elements for the upper 212 and lower 214 shutters must be able to withstand the pressures and loads associated with a gravel packing process. Typically, such pressures are about 2000 psi to 3000 psi (140 to 211 kg / cm2). The elements for the shutters 212, 214 must also withstand pressure loads, due to differential pressures from the well and / or reservoir caused by natural failures, depletion, production or injection. Production operations may involve selective production or production allocation to satisfy regulatory requirements. Injection operations may involve selective fluid injection to maintain strategic reservoir pressure. Injection operations can also involve selective stimulation in acid fracturing, matrix acidification, or removal of formation damage.
[0089] [0089] The surface or sealing elements of mechanically placed shutters 212, 214 need only be in the order of inches to affect an adequate hydraulic seal. In one aspect, the elements are each about 6 inches (1.52 cm) to about 24 inches (70.0 cm) in length.
[0090] [0090] The elements for the shutters 212, 214 are preferably cup-like elements. Cup-like elements are well known for use in jacketed hole completions. However, they are generally not known for use in open-hole completions, as they are not designed to expand into fit with a hole-open diameter. The preferred cup-like nature of the sealing surfaces of the closure elements 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 packaging operation gravel.
[0091] [0091] The top 212 and bottom 214 shutters are placed before a gravel pack installation process. As more fully described below, the plugs 212, 214 can be placed by sliding a release sleeve. This, in turn, allows hydrostatic pressure to act down against a piston mandrel. The piston mandrel acts downwards under centralizing elements and / or plugs, causing them to expand against the shaft wall 201. The expandable parts of the upper plugs 212 and lower 214 are expanded in contact with the surrounding wall 201, in order to straddle the annular region 202 at a selected depth throughout the open-hole completion 120.
[0092] [0092] Figure 2 shows a chuck at 215. This can be representative of the piston chuck and other chucks used in shutters 212, 214, as described more fully below.
[0093] [0093] The upper shutters 212 and lower 214 can generally be mirror images of each other, except for release gloves or other locking mechanisms. The unilateral movement of a displacement tool (shown in and discussed in relation to Figures 7A and 7B) will allow the shutters 212, 214 to be activated in sequence or simultaneously. The lower plug 214 is activated first, followed by the upper plug 212, when the displacement tool is pulled up through an internal mandrel (shown in and discussed in relation to Figures 6A and 6B). A short spacing is preferably provided between the upper 212 and lower 214 shutters.
[0094] [0094] The filling units 210 ’, 210” help to control and manipulate fluids produced from different zones. In this regard, the filling units 210 ’, 210” allow the operator to seal a production or injection interval, depending on the function of the well. The installation of the filling units 210 ', 210 ”in the initial completion allows an operator to interrupt the production of one or more zones during the life of the well, to limit the production of water or, in some examples, an undesirable non- condensable, such as hydrogen sulfide.
[0095] [0095] Shutters have historically not been installed when an open-hole gravel package is used, due to the difficulty in forming a seal along a part of the hole, and because of the difficulty in forming an complete gravel package above and below the shutter. U.S. Publication of Patent Applications Nos. 2009/0294128 and related 2010/0032158 describes apparatus' and methods for packing gravel into a borehole well after a shutter has been placed in a completion interval. Zonal isolation, in completions packaged with open-hole gravel, can be provided using a filling element and secondary (or “alternative”) flow paths, to enable both zonal insulation and gravel packaging in the flow path. alternative.
[0096] [0096] Certain technical challenges have remained with respect to the methods described in Pub. U.S. Nos. 2009/0294128 and 2010/0032158, particularly in relation to the shutter. Orders claim 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 filling element from such materials requires that the filling element meets a particularly high level of performance. In this regard, the filling 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 claim that the plug can be an expansion rubber element that expands in the presence of hydrocarbons, water or other stimuli. However, known swelling elastomers typically require about 30 days or more to fully expand in a sealed fluid fitting with the surrounding rock formation. Therefore, improved shutters and zonal isolation apparatus ’are offered here.
[0097] [0097] Figure 3A shows an illustrative filling unit 300 providing an alternative flow path for a gravel sludge. The filling unit 300 is seen in lateral view in cross section. The obturator unit 300 includes several components, which can be used to seal an annular crown along the bore 120.
[0098] [0098] The shutter unit 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 of a specific length 316, such as about 40 feet (12.2 meters). The main body section 302 comprises individual pipe joints, which will be between 10 feet (3.0 meters) and 50 feet (15.2 meters) in length. Tube joints are typically threaded end-to-end to form a main body section 302 according to length 316.
[0099] [0099] The obturator unit 300 also includes opposing mechanically placed obturators 304. The mechanically placed obturators 304 are shown schematically, and are generally in accordance with mechanically placed obturator elements, 212 and 214 of Figure 2. The obturators 304 preferably include elastomeric type elements -cup that are less than 1 foot (0.3 meters) long. As described below, the shutters 304 have alternative flow channels that only allow the 304 shutters to be placed before a gravel sludge is circulated within the well.
[0100] [00100] A short spacing 308 is provided between the mechanically placed shutters 304. The spacing is seen at 308. When the 304 shutters are mirror images of each other, the cup-like elements are able to withstand fluid pressure both above as below the filling unit.
[0101] [00101] The obturator unit 300 also includes a plurality of bypass tubes. The bypass tubes are seen schematically at 318. The bypass tubes 318 can also be referred to as transport tubes or bridge tubes. The bypass tubes 318 are empty sections of tube having a length that extends along the length 316 of the mechanically placed shutters 304 and the spacing 308. The bypass tubes 318 of the obturator unit 300 are configured to engage in and form a seal with bypass tubes in connected sand sieves, as discussed below.
[0102] [00102] Bypass tubes 318 provide an alternative flow path through mechanically placed shutters 304 and intermediate spacing 308. This allows bypass tubes 318 to transport a carrier fluid along with gravel at different intervals 112, 114 and 116 from the borehole 120 of well 100.
[0103] [00103] The shutter unit 300 also includes connection members. These can represent traditional threaded couplings. First, a narrow section 306 is provided at a first end of the obturator unit 300. The narrow section 306 has external threads for connecting with a threaded coupling box of a sand sieve or other pipe. Then, a notched or externally threaded section 310 is provided at a second opposite end. The threaded section 310 serves as a coupling box, for receiving an outer threaded end of a sand sieve or other tubular member.
[0104] [00104] The narrow section 306 and the threaded section 310 can be made of steel or alloy steel. Each narrow section 306 and threaded section 310 is 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 filling unit 300 and the sand control devices or other pipe segments.
[0105] [00105] A cross-sectional view of the obturator unit 300 is shown in Figure 3B. Figure 3B is taken along line 3B-3B in Figure 3A. Several bypass tubes 318 are placed radially and equidistant around the base tube 302. A central hole 305 is shown inside the base tube 302. The central hole 305 receives production fluids during production operations and transports them to the pipeline. of production 130.
[0106] [00106] Figure 4A shows a side view in cross section of an insulation device 400, in one embodiment. The zonal isolation apparatus 400 includes the shutter unit 300 of Figure 3A. In addition, sand control devices 200 have been connected at opposite ends to narrow section 306 and notched section 310, respectively. The bypass tubes 318 of the filling unit 300 are seen connected to the bypass tubes 218 of the sand control devices 200. The bypass tubes 218 represent filling tubes, which allow the flow of gravel mud between an annular well crown and the tubes 218. The bypass tubes 218 of the sand control devices 200 optionally include valves 209 to control the flow of gravel sludge, such as to fill tubes (not shown).
[0107] [00107] Figure 4B provides a cross-sectional view of the zonal isolation device 400. Figure 4B taken along line 4B-4B of Figure 4A. This is cut through one of the sand sieves 200. In Figure 4B, the notched or perforated base tube 205 is seen. This is in accordance with the base tube 205 of Figures 1 and 2. The central hole 105 is shown inside base tube 205 to receive production fluids during production operations.
[0108] [00108] An outer mesh 220 is disposed immediately around the base tube 205. The outer mesh 220 preferably comprises a wire mesh or wires helically wound around the base tube 205, and serves as a sieve. In addition, bypass tubes 218 are placed radially and equidistant around outer mesh 205. This means that the sand control devices 200 provide an external embodiment for bypass tubes 218 (or alternative flow channels).
[0109] [00109] The configuration of the bypass tubes 218 is preferably concentric. This is seen from the cross-sectional view of Figure 3B. However, bypass tubes 218 can be eccentrically designed. For example, Figure 2B of Pat. No. 7,661,446 discloses a "Prior Art" arrangement for a sand control device in which filling tubes 208A and transport tubes 208b are placed external to the base tube 202 and surrounding filter media 204.
[0110] [00110] In the arrangement of Figures 4A and 4B, the bypass tubes 218 are external to the filtration medium, or external mesh 220. The configuration of the sand control device 200 can be modified. In this regard, bypass tubes 218 can be moved internally to filter medium 220.
[0111] [00111] Figure 5A shows a cross-sectional view of a zonal isolation device 500 in an alternate embodiment. In this embodiment, the sand control devices 200 are connected again at ends opposite the narrow section 306 and the notched section 310, respectively, of the filling unit 300. In addition, the bypass tubes 318 of the filling unit 300 are seen connected to the bypass tubes 218 of the sand control unit 200. However, in Figure 5A, the sand control unit 200 uses internal bypass tubes 218, meaning that bypass tubes 218 are arranged between the base tube 205 and the surrounding screen 220.
[0112] [00112] Figure 5B provides a side cross-sectional view of the zonal isolation apparatus 500. Figure 5B is taken along line B-B of Figure 5A. This is cut through one of the sand screens 200. In Figure 5B, the carved or perforated base tube 205 is seen again. This is according to the base tube 205 of Figures 1 and 2. The central hole 105 is shown inside the base tube 205, to receive production fluids during production operations.
[0113] [00113] The bypass tubes 218 are placed radially and equidistant around the base tube 205. The bypass tubes 218 reside immediately around the base tube 205 and within a surrounding filter medium 220. This means that the devices sand control units 200 of Figures 5A and 5B provide an internal embodiment for bypass tubes 218.
[0114] [00114] An annular region 225 is created between the base tube 205 and the surrounding outer mesh or filter medium 220. The annular region 225 accommodates the influx of production fluids into a well. The outer wound wire 220 is supported by a plurality of support ribs extending radially 222. The ribs 222 extend through annular region 225.
[0115] [00115] Figures 4A and 5A present arrangements for connecting sand control joints to a filling unit. The bypass tubes 318 (or alternative flow channels) within the shutters fluidly connect to the bypass tubes 218 along the sand sieves 200. However, the zonal isolation device arrangements 400, 500 of Figures 4A-4B and 5A-5B are illustrative only. In an alternative arrangement, a distribution system can be used to provide fluid communication between bypass tubes 218 and bypass tubes 318.
[0116] [00116] Figure 3C is a cross-sectional view of the obturator unit 300 of Figure 3A, in an alternative embodiment. In this arrangement, bypass tubes 218 are distributed 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 confined by the particular design and arrangement of the bypass tubes 318, since the mud diversion is provided for the filling unit 210. However, it is preferred that a concentric arrangement is employed.
[0117] [00117] It should also be noted that the coupling mechanism of the sand control devices 200 with the shutter unit 300 may include a sealing mechanism (not shown). The sealing mechanism prevents leakage of the mud that is in the alternative flow path formed by the bypass tubes. Examples of such sealing mechanisms are described in U.S. Patent No. 6,464,261; Intl. Pat. WO 2004/094769; Intl. Pat. No. W02005 / 031105; Publ. Pat. No. 2004/0140089; Publ. Pat. No. 2005/0028977; Publ. Pat. No. 2005/0061501; and Publ. Pat. No. 2005/0082060.
[0118] [00118] As noted, the shutter unit 300 includes a pair of mechanically placed shutters 304. When using the shutter unit 300, shutters 304 are beneficially placed before the slurry is injected and the gravel packet is formed. This requires a single plug arrangement, in which bypass tubes are provided for an alternate flow channel.
[0119] [00119] The 304 shutters of Figure 3A are shown schematically. However, Figures 6A and 6B provide more detailed views of a mechanically placed obturator 600 that can be used in the obturator unit of Figure 3A, in one embodiment. The views in Figures 6A and 6B provide lateral cross-sectional views. In Figure 6A, the shutter 600 is in its insertion position, while in Figure 6B the shutter 600 is in its placement position.
[0120] [00120] The obturator 600 first includes an inner mandrel 610. The inner mandrel 610 defines an elongated tubular body forming a central hole 605. The central hole 605 provides a primary flow path for the production fluids through the obturator 600. After installation and beginning of production, the central hole 605 transports production fluids to the hole 105 of the sand sieves 200 (seen in Figures 4A and 4B) and the production pipe 130 (seen in Figures 1 and 2).
[0121] [00121] The plug 600 also includes a first end 602. Threads 604 are placed along the inner mandrel 610 of the first end 602. Illustrative threads 604 are external threads. A housing connector 614, having internal threads at both ends, is connected or threaded to the threads 604 of the first end 602. The first end 602 of the inner mandrel 610 with the housing connector 614 is called the housing end. The second end (not shown) of the internal mandrel 610 has external threads and is called the pin end. The pin end (not shown) of the internal mandrel 610 allows the plug 600 to be connected to the box end of a sand sieve or other tubular body, such as an independent sieve, a measuring module, a production pipe, or a blank tube.
[0122] [00122] The housing connector 614, at the end of the housing 602, allows the plug 600 to be connected to the pin end of a sand sieve or other tubular body, such as an independent sieve, a measuring module, a production, or a blank tube.
[0123] [00123] The internal mandrel 610 extends along the length of the plug 600. The internal mandrel 610 can be composed of multiple connected segments, or together. The inner mandrel 610 has a slightly smaller inner diameter near the first end 602. This is due to a machining shoulder 606 machined in the inner mandrel. As will be explained more fully below, the placement shoulder 606 captures a release sleeve 710 in response to the mechanical force applied by a placement tool.
[0124] [00124] The plug 600 also includes a piston mandrel 620. The piston mandrel 620 generally extends from the first end 602 of the plug 600. The piston mandrel 620 can be composed of multiple connected segments, or joints. The piston mandrel 620 defines an elongated tubular body that resides circumferentially and substantially concentric to the inner mandrel 610. An annular crown 625 is formed between the inner mandrel 610 and the surrounding piston mandrel 620. The annular crown 625 beneficially provides a secondary flow path or alternative flow channels for fluids.
[0125] [00125] In the arrangement of Figures 6A and 6B, the alternative flow channels defined by the annular crown 625 are external to the internal mandrel 610. However, the plug could be reconfigured so that the alternative flow channels are within the hole 605 of the mandrel. internal 610. In any of the examples, the alternative flow channels are “along” the internal mandrel 610.
[0126] [00126] The ring crown 625 is in fluid communication with the secondary flow path of another downhole tool (not shown in Figures 6A and 6B). Such a separate tool can be, for example, the sand sieves 200 of Figures 4A and 5A, or a blank tube, or other tubular body. The tubular body may or may not have alternative flow channels.
[0127] [00127] The plug 600 also includes a 630 coupling. The 630 coupling is connected and sealed (for example, via elastomeric “o” rings) to the piston mandrel 620 of the first end 602. The 630 coupling is then threaded and attached to the connector housing 614, which is threadably connected to the internal chuck 610, to prevent relative rotational movement between the internal chuck 610 and the coupling 630. A first torque screw is shown at 632 to secure the coupling to the housing connector 614.
[0128] [00128] In one aspect, a NACA (National Advisory Committee for Aeronautics) 634 key is also employed. The NACA 634 wrench is placed inside the 630 coupling, and external to a 614 threaded housing connector. A first torque screw is provided at 632, connecting the 630 coupling to the NACA 634 wrench and then to the 614 housing connector. A second screw torque is provided at 636 by connecting the 630 coupling to the NACA 634 key. The NACA-shaped keys can (a) secure the 630 coupling to the internal mandrel 610, via housing connector 614, (b) prevent the 630 coupling from rotating around of the inner mandrel 610, and (c) streamline the mud flow along the annular crown 612 to reduce friction.
[0129] [00129] Within the obturator 600, the annular crown 625 around the inner mandrel 610 is isolated from the main hole 605. In addition, the annular crown 625 is isolated from an annular crown of the surrounding well (not shown). The annular crown 625 allows the transfer of gravel sludge from alternative flow channels (such as bypass tubes 218) through plug 600. Thus, annular crown 625 becomes the alternative flow channel (s) for the shutter 600.
[0130] [00130] In operation, an annular space 612 resides in the first end 602 of the plug 600. The annular space 612 is disposed between the housing connector 614 and the coupling 630. The annular space 612 receives mud from the alternative flow channels of a body connected tubular, and supplies the mud to the annular crown 625. The tubular body can be, for example, an adjacent sand sieve, a blank tube, or a zonal isolation device.
[0131] [00131] The plug 600 also includes a charge shoulder 626. Charge shoulder 626 is placed near the end of piston mandrel 620, where coupling 630 is connected and sealed. A solid section at the end of the piston mandrel 620 has an inside diameter and an outside diameter. The load shoulder 626 is placed along the outside diameter. The outer diameter is threaded and is rocky connected to the inner mandrel 610. At least one alternative flow channel is formed between the inner and outer diameters to connect the flow between the annular space 612 and the annular crown 625.
[0132] [00132] The load relief 626 provides a point containing load. During apparatus operations, a load collar or harness (not shown) is placed around the load boss 626 to allow the shutter 600 to be harvested and supported with conventional elevators. The charge shoulder 626 is then temporarily used to support the weight of the shutter 600 (and any connected completion devices, such as sand sieve joints introduced into the well), when placed on the rotating floor of an apparatus. The load can then be transferred from the load boss 626 to a pipe thread connector, such as the housing connector 614, then to the inner mandrel 610 or base pipe 205, which is a pipe threaded to the housing connector 614 .
[0133] [00133] The plug 600 also includes a piston housing 640. The piston housing 640 resides around and is substantially concentric to the piston mandrel 620. The plug 600 is configured to cause the piston housing 640 to move axially. along and in relation to piston mandrel 620. Specifically, piston housing 640 is driven by hydrostatic downhole pressure. The piston enclosure 640 can be composed of multiple connected segments, or together.
[0134] [00134] The piston housing 640 is held in position along the piston mandrel 620 during insertion. Piston housing 640 is secured using a release sleeve 710 and release key 715. Release sleeve 710 and release key 715 prevent relative translational movement between piston housing 640 and piston mandrel 620. A release key 715 penetrates through both piston mandrel 620 and internal mandrel 610.
[0135] [00135] Figures 7A and 7B provide enlarged views of release sleeve 710 and release key 715 for shutter 600. Release sleeve 710 and release key 715 are held in place by a shear pin 720. In In Figure 7A, the shear pin 720 has not been sheared, and the release sleeve 710 and release key 715 are retained in position along the inner mandrel 610. However, in Figure 7B, the shear pin 720 has been sheared, and the release sleeve 710 was carried along an inner surface 608 of the inner mandrel 610.
[0136] [00136] In each of Figures 7A and 7B, the internal mandrel 610 and the surrounding piston mandrel 620 are seen. In addition, piston housing 640 is seen from outside piston mandrel 620. The three tubular bodies, representing inner mandrel 610, piston mandrel 620, and piston housing 640, are secured together in relation to the translational or rotational movement, by four release keys 715. Only one of the release keys 715 is seen in Figure 7A; however, four release keys 715 are radially visible in the cross-sectional view of Figure 6E, described below.
[0137] [00137] The release key 715 resides inside a keyhole 615. The keyhole 615 extends through the internal mandrel 610 and the piston mandrel 620. The release key 715 includes a shoulder 734. The shoulder 734 resides within a recess of the shoulder 624 in the piston mandrel 620. The recess of the shoulder 624 is large enough to allow the shoulder 734 to move radially inward. However, such movement is restricted in Figure 7A by the presence of the release sleeve 710.
[0138] [00138] It is observed that the annular crown 625 between the internal mandrel 610 and the piston mandrel 620 is not seen in figure 7A or 7B. This is because the ring ring 625 does not extend across the cross section, or is too small. Instead, annular crown 625 employs separate radially spaced channels that preserve support for release keys 715, as best seen in Figure 6E. In other words, the large channels composing the annular crown 625 are located far from the material of the internal mandrel 610, which surrounds the keyholes 615.
[0139] [00139] At each location of the release key, a keyhole 615 is machined through the internal chuck 610. Keyholes 615 are drilled to accommodate the respective release keys 715. If there are four release keys 715, there will be four discrete protuberances spaced circumferentially to significantly reduce annular crown 625. The remaining area of annular crown 625, between adjacent protuberances, allows flow, in the alternate flow channel 625, to bypass release key 715.
[0140] [00140] Lumps can be machined as part of the inner mandrel 610 body. More specifically, the material composing the inner mandrel 610 can be machined to form the lumps. Alternatively, the protrusions can be machined as a separate, short release chuck (not shown), which is then threaded to the internal chuck 610. Alternatively, the protrusions can be a separate spacer attached between the internal chuck 610 and the piston chuck 620 by welding or other means.
[0141] [00141] Also, it is observed that, in Figure 6A, the piston mandrel 620 is shown as an integral body. However, the part of the piston mandrel 620 where the keyholes 615 are located can be a short, separate release enclosure. This separate enclosure is then connected to piston mandrel 620.
[0142] [00142] Each release key 715 has an opening 732. Similarly, release sleeve 710 has an opening 722. Opening 732 in release key 715 and opening 722 in release sleeve 710 are sized and configured to receive a pin shear. The shear pin is seen at 720. In Figure 7A, the shear pin 720 is retained within the openings 732, 722 by the release sleeve 710. However, in Figure 7B, the shear pin 720 has been sheared, and only a portion pin 720 remains visible.
[0143] [00143] An outer edge of the release key 715 has a grooved surface, or teeth. The teeth of the release wrench 715 are shown in 736. The teeth 736 of the release wrench 715 are angled and configured to join with a reciprocal grooved surface within the piston housing 640. The grooved surface (or teeth) of the housing piston 640 is shown at 646. Teeth 646 reside on an inner face of piston housing 640. When engaged, teeth 736, 646 prevent movement of piston housing 640 in relation to piston chuck 620 or internal chuck 610 Preferably, the grooved joint surface or teeth 646 reside on the inner face of a separate short external release sleeve, which is then threaded to piston housing 640.
[0144] [00144] Now returning to Figures 6A and 6B, the plug 600 includes a centering member 650. The centering member 650 is driven by the movement of the piston housing 640. The centering member 650 can be, for example, as described in US Order Publication No. 2011/0042106.
[0145] [00145] Shutter 600 further includes a sealing element 655. When centering member 650 is actuated and centralizes shutter 600 within the surrounding well, piston housing 640 continues to drive sealing element 655, as described in Publication US Patent No. 2009/0308592.
[0146] [00146] In Figure 6A, the centering member 650 and the sealing element 655 are in their insertion positions. In Figure 6B, the connected centering member 650 and sealing element 655 were activated. This means that the piston housing 640 has been moved along the piston mandrel 620, causing both the centering member 650 and the sealing element 655 to engage the surrounding well wall.
[0147] [00147] An anchoring system, as described in WO 2010/084353, can be used to prevent piston housing 640 from going forward. This prevents the 655 cup-type element from contracting.
[0148] [00148] As noted, the movement of piston enclosure 640 occurs in response to the hydrostatic pressure of well fluids, including gravel mud. At the insertion position of the plug 600 (shown in Figure 6A), the piston housing 640 is held in position by the release sleeve 710 and associated piston wrench 715. This position is shown in Figure 7A. In order to place the plug 600 (according to Figure 6B), the release sleeve 710 must be moved out of the release key 715 mode, so that the teeth 736 of the release key 715 do not stay any longer fitted with the teeth 646 of the piston housing 640. This position is shown in Figure 7B.
[0149] [00149] To move the release sleeve 710, a placement tool is used. An illustrative placement tool is shown at 750 in Figure 7C. The placement tool 750 defines a short cylindrical body 755. Preferably, the placement tool 750 is introduced into the well with a column of wash tubes (not shown). The movement of the wash tube column along the well can be controlled on the surface.
[0150] [00150] An upper end 752 of the insertion tool 750 is made up of several radial pincer fingers 760. The pincer fingers 760 collapse when subjected to sufficient internal force. In operation, the clamp fingers 760 clamp in a profile 724 formed along the release sleeve 710. The clamp fingers 760 include enlarged surfaces 762 that join with or clamp in the profile 724 of the release key 710. On engagement, the clamping tool Placement 750 is pulled or raised into the well. The placement tool 750 then pulls the release sleeve 710 with enough force to cause the shear pins 720 to shear. Once the shear pins 720 are sheared, the release sleeve 710 is free to travel upward along the inner surface 608 of the inner mandrel 610.
[0151] [00151] As noted, the placement tool 750 can be introduced into the well with a wash tube. The placement tool 750 can simply be a perforated part of the wash tube body. Preferably, however, the laying tool 750 is a separate tubular body 755 that is threadably connected to the wash tube. In Figure 7C, a connection tool is provided at 770. The connection tool 770 includes external threads 775 to connect with a drill string or other insertion tube. The connection tool 770 extends inside the body 755 of the placement tool 750. The connection tool 770 can extend all the way through the body 755 to connect to the flush tube or other device, or it can connect internal threads (not seen) inside the body 755 of the laying tool 750.
[0152] [00152] Returning to Figures 7A and 7B, the path of the release sleeve 710 is limited. In this regard, a first or top end 726 of the release sleeve 710 stops against the shoulder 606 along the inner surface 608 of the inner mandrel 610. The length of the release sleeve 710 is short enough to allow the release sleeve 710 unclog opening 732 of release key 715. When fully moved, release key 715 moves radially inward, pushed by the rough profile of piston housing 640, when hydrostatic pressure is present.
[0153] [00153] When fully moved, the release key 715 moves radially inward, pushed by the rough profile of the piston enclosure 640, when hydrostatic pressure is present.
[0154] [00154] The shear of the pin 720 and the movement of the release sleeve 710 also allow the release key 715 to disengage from the piston housing 640. The recess of the shoulder 624 is dimensioned to allow the shoulder 734 of the release key 715 to fall or disengaging teeth 646 from piston housing 640, since release sleeve 710 is unobstructed. The hydrostatic pressure then acts on piston housing 640 to translate inwardly with respect to piston mandrel 620.
[0155] [00155] After the shear pins 720 have been sheared, the container 640 is free to slide along an external surface of the inner mandrel 620. To accomplish this, the hydrostatic pressure of the annular crown 625 acts on a shoulder 642 of the enclosure. piston 640. This is best seen in Figure 6B. The shoulder 642 serves as a thrust bearing surface. A fluid orifice 628 is provided through piston mandrel 620 to allow fluid to access boss 642. Beneficially, fluid orifice 628 allows a higher pressure than hydrostatic pressure to be applied during gravel packing operations . Pressure is applied to the piston housing 640 to ensure that the plug elements 655 engage against the surrounding well.
[0156] [00156] The shutter 600 also includes a measuring device. When the piston housing 640 travels along the piston mandrel 620, a measuring hole 664 regulates the speed at which the piston housing travels along the piston mandrel, thus decreasing the movement of the piston housing and regulating the shutter placement speed 600. To better understand the aspects of the mechanically placed shutter illustrative 600, several cross-sectional views are provided. These are seen from Figures 6C, 6D, and 6F.
[0157] [00157] First, Figure 6C is a cross-sectional view of the mechanically placed plug of Figure 6A. The view is taken through line 6C-6C in Figure 6A. The 6C-6C line is taken through one of the torque screws 636. The torque screw 636 connects the coupling 630 with the NACA 634 wrench.
[0158] [00158] Figure 6D is a cross-sectional view of the mechanically placed plug of Figure 6A. The view is taken through line 6D-6D of Figure 6B. The 6D-6D line is taken through another of the torque screws 632. The torque screw 632 connects the coupling 630 to the housing connector 614, which is threaded to the internal chuck 610.
[0159] [00159] Figure 6E is a cross-sectional view of the mechanically placed obturator 600 of Figure 6A. The view is taken through line 6E-6E of Figure 6A. Line 6E-E is taken through release key 715. It can be seen that release key 715 passes through piston spindle 620 and into internal spindle 610. It is also noted that the alternative flow channel 625 resides between release keys 715.
[0160] [00160] Figure 6F is a cross-sectional view of the mechanically placed plug 600 of Figure 6A. The view is taken through line 6F-6F in Figure 6B. Line 6F-6F is taken through fluid holes 628 inside piston mandrel 620. When fluid moves through fluid holes 628 and pushes boss 642 of piston housing 640 away from holes 628, an annular space 672 is created and elongated between piston mandrel 620 and piston housing 640.
[0161] [00161] Once the bypass shutter 600 is placed, gravel packing operations can begin. Figures 8A to 8J show stages of a gravel packing procedure, in one embodiment. The gravel packing procedure employs a filling unit having alternative flow channels. The obturator unit can be according to the obturator unit 300 of Figure 3A. The shutter unit 300 will have mechanically placed shutters 304. These shutters 304 can be according to the shutter 600 of Figs. 6A and 6B.
[0162] [00162] In Figures 8A to 8J, sand control devices are used with a gravel packing procedure. In Figure 8A, a well 800 is shown. Illustrative well 800 is a horizontal, open-hole well. Well 800 includes a wall 805. Two different production intervals are indicated along horizontal well 800. These are shown in 810 and 820. Two sand control devices 850 have been introduced in well 800. Separate sand control devices 850 are provided at each production interval 810, 820. The fluids in well 800 were displaced using a clearing fluid 814.
[0163] [00163] Each of the sand control devices 850 is comprised of a base tube 854 and a surrounding sand sieve 856. Base tube 854 has slits or perforations to allow fluid to flow into the base tube 854 Each sand control device 850 also includes flow paths. These can be according to branch tubes 218 of Figure 4B or Figure 5B. Preferably, the bypass tubes are internal bypass tubes arranged between the base tubes 854 and the sand sieves 856 of the annular region shown in 852.
[0164] [00164] The sand control devices 850 are connected via an intermediate shutter unit 300. In the arrangement of Figure 8A, the shutter unit 300 is installed at the interface between the production intervals 810, 820. More than one shutter unit 300 can be incorporated.
[0165] [00165] In addition to the sand control devices 850, a wash tube 840 was lowered into well 800. Wash tube 840 is introduced into well 800 below a crossover tool or a gravel pack service tool (not shown), which is attached to the end of an 835 drill pipe or other work column. The washing tube 840 is an elongated tubular member that extends into the sand sieves 850. The washing tube 840 assists in the circulation of the gravel sludge during a gravel packing operation, and is subsequently removed. Attached to the washing tube 840 is a displacement tool, just like the displacement tool 750 shown in Figure 7C. The displacement tool 750 is positioned below the shutter 300.
[0166] [00166] In Figure 8A, a crossover tool 845 is placed at the end of the drill pipe 835. The crossover tool 845 is used to direct the injection and circulation of the gravel sludge, as discussed in more detail below.
[0167] [00167] A separate plug 815 is connected to the crossover tool 845. The plug 815 and the connected crossover tool 845 are temporarily positioned within a column of production liners. Together, the plug 815, the crossover tool 845, the elongated wash tube 840, the displacement tool 750, and the gravel pack screens 850 are inserted into the lower end of the well 800. The plug 815 is then placed in the production liner 830. The crossover tool 845 is then released from shutter 815 and is free to move, as shown in Figure 8B.
[0168] [00168] In Figure 8B, the obturator 815 is placed in the column of production liner tubes 830. This means that the obturator 815 is actuated to extend liquid clays and an elastomeric sealing element against the surrounding column of liner tubes 830. The shutter 815 is placed above the intervals 810 and 820, which are to be packed with gravel. The shutter 815 seals the gaps 810 and 820 of the parts of the well 800 above the shutter 815.
[0169] [00169] After the plug 815 is placed, as shown in Figure 8B, the crossover tool 845 is moved upwards in an inverse position. Circulation pressures can be measured in this position. A carrier fluid 812 is pumped drill pipe 835 below and placed inside an annular crown, between drill pipe 835 and the surrounding production liner tube 830, above plug 815. The carrier fluid is a gravel-carrying fluid, which is the liquid component of the gravel packing sludge. Carrier fluid 812 displaces unobstructed displacement fluid 814 onto plug 815, which can be an oil-based fluid, such as conditioned NAF. Carrier fluid 812 displaces displacement fluid 814 in the direction indicated by arrows “C”.
[0170] [00170] Next, the 304 shutters are placed, as shown in Figure 8C. This is done by pulling the displacement tool, located under the obturator unit 300, on the washing tube 840 and upwards beyond the obturator unit 300. More specifically, the mechanically placed shutters 304 of the obturator unit 300 are placed. The shutters 304 can be, for example, the shutter 600 of Figures 6A and 6B. The plug 600 is used to isolate the annulus formed between the sand sieves 856 and the wall surrounding 805 of the well 800. The wash tube 840 is lowered to an inverse position. While in the reverse position, as shown in Figure 8D, the carrier fluid 812 with gravel can be placed inside the drill pipe 835 and used to force the clear displacement fluid 814 through the wash tube 840 and upward from the annular crown formed between the drill pipe 835 and the production liner pipe 830, above the plug 815, as shown by arrows "C".
[0171] [00171] In Figures 8D to 8F, the crossover tool 845 can be moved from the circulation position to the gravel package of the first subsurface interval 810. In Figure 8D, the carrier fluid with gravel 816 begins to create a gravel package within the production interval 810, above the annular crown plug 300, between the sand sieve 856 and the wall 805 of the borehole well 800. Fluids flow out of the sand sieve 856 and return through the wash tube 840, as indicated by the “D” arrows.
[0172] [00172] In Figure 8E, a first pack of gravel 860 begins to form above the plug 300. The pack of gravel 860 forms around the sand sieve 856 and towards the plug 815. The carrier fluid is circulated below the plug 300 and to the base of the well 800. The carrier fluid 812 without gravel flows to the wash tube 840 as indicated by arrows “C”.
[0173] [00173] In Figure 8F, the gravel packing process continues to form the gravel pack 860 towards plug 815. Sand sieve 856 is now being fully coated by gravel pack 860 above plug 300. The carrier fluid 812 continues to be circulated under the plug 300 and to the base of the well 800. The carrier fluid 812 without gravel flows to the washing tube 840, as indicated by the arrows “C” again.
[0174] [00174] Since the gravel package 860 is formed in the first gap 810 and the sand sieves, above the obturator 300, are coated with gravel, the gravel carrier fluid 816 is forced through the bypass pipes (shown in 318 of Figure 3B). The gravel carrier fluid 816 forms the gravel package 860 of Figures 8G to 8J.
[0175] [00175] In Figure 8G, the carrier fluid with gravel 816 now flows within the production range 820, below the plug 300. The carrier fluid 816 flows through the bypass tubes and plug 300 and then out of the sieve. sand 856. The carrier fluid 816 then flows into the annular crown, between the sand sieve 856 and the wall 805 of the well 800, and returns to the wash tube 840. The flow of the carrier fluid with gravel 816 is indicated by the arrows “ D ”, while the flow of carrier fluid in the washing tube 840 without the gravel is indicated at 812, shown by the arrows“ C ”.
[0176] [00176] It is observed here that the mud only flows through the bypass channels along the shutter sections. After that, the sludge will go into the alternative flow channels of the next adjacent sieve joint. Alternative flow channels have both transport and filling tubes distributed at each end of a sieve joint. The filling tubes are provided along the sand sieve joints. The filling tubes represent side nozzles, which allow the mud to fill any spaces in the annular crown. The transport pipes will take the mud further downstream.
[0177] [00177] In Figure 8H, the gravel package 860 is beginning to form below the shutter 300 and around the sand sieve 856. In Figure 81, the gravel package continues to develop the gravel package 860 at the base of the well 800 above plug 300. In Figure 8J, gravel pack 860 was formed at the base of well 800 above plug 300. Sand sieve 856, below plug 300, was lined by gravel pack 860. The pressure of surface treatment increases, to indicate that the annular space, between the sand sieves 856 and the wall 805 of the well 800, is entirely of packed gravel.
[0178] [00178] Figure 8K shows the drilling column 835 and the washing tube 840, of Figures 8A to 8J, having been removed from well 800. The coating tube 830, the base tubes 854, and the sand sieves 856 remain in well 800 over the upper production intervals 810 and lower 820. Shutter 300 and gravel packs 860 remain fitted in open borehole 800, following the completion of the gravel packing procedure of Figures 8A to 8J. Well 800 is now ready for production operations.
[0179] [00179] As mentioned above, once a well has been packed with gravel, the operator can choose to isolate a selected range from the well and discontinue production from that range. To demonstrate how a well gap can be isolated, Figures 9A and 9B are provided.
[0180] [00180] First, Figure 9A is a cross-sectional view of a 900A well. Well 900A is generally constructed according to well 100 in Figure 2. In Figure 9A, well 900A 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 9A).
[0181] [00181] Subsurface interval 114 may be part of a subsurface formation that once produced hydrocarbons in commercially viable quantities, but has now undergone significant gas or water invasion. Alternatively, the subsurface gap 114 may be a formation that was originally a water or aquitard zone or is otherwise substantially saturated with aqueous fluid. In either example, the operator decided to seal the influx of forming fluids from the range 114 into well 900A.
[0182] [00182] A sand sieve 200 was placed in well 900A. The sand screen 200 is in accordance with the sand control device 200 of Figure 2. In addition, a base tube 205 is seen 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-wrapped screen, or other radial filter media 207. The base tube 205 and the surrounding filter media 207 preferably comprise a series of end-connected joints -with-end. The joints are in ideal condition from about 5 to 45 feet in length.
[0183] [00183] Well 900A has an upper filling unit 210 ’and a lower filling unit 210”. The upper obturator unit 210 'is disposed close to the interface of the upper gap 112 and the intermediate gap 114, while the lower obturator unit 210 "is arranged near the interface of the intermediate gap 114 and the lower gap 116. Each of the closure units 210' , 210 "is preferably in accordance with the shutter unit 300 of Figures 3A and 3B. In this regard, the shutter units 210 ', 210 ”will have opposing mechanically placed shutters 304. The mechanically placed shutters are shown in Figure 9A at 212 and 214. The mechanically placed shutters 212, 214 can be in accordance with the shutter 600 of Figures 6A and 6B. The shutters 212, 214 are spaced apart, as shown by the spacing 216.
[0184] [00184] The double shutters 212, 214 are mirror images of each other, except for the release gloves (for example, release sleeve 710 and associated shear pin 720). As noted above, the unilateral movement of a displacement tool (such as displacement tool 750) shears the shear pins 720 and moves the release sleeves 710. This allows the closing elements 655 to be activated in sequence, the bottom one first and then the top one.
[0185] [00185] Well 900A is completed as an open-hole completion. A pack of gravel was placed in well 900A, to help prevent the influx of granular particles. The gravel packaging is indicated as spackles in the annular crown 202, between the filter medium 207 of the sand sieve 200 and the surrounding wall 201 of the well 900A.
[0186] [00186] In the arrangement of Figure 9A, the operator wishes to continue producing forming fluids from the upper 112 and lower 116 intervals, while sealing the intermediate interval 114. The upper 112 and lower 116 intervals are formed of a sand matrix or other rock that is permeable to fluid flow. To accomplish this, a straddle plug 905 was placed inside the sand sieve 200. Straddle plug 905 is placed substantially through the intermediate gap 114, to prevent the influx of forming fluids from the intermediate gap 114.
[0187] [00187] Straddle plug 905 comprises a mandrel 910. Mandrel 910 is an elongated tubular body having an upper end adjacent to the upper obturator unit 210 ', and a lower end adjacent to the lower obturator unit 210 ”. The straddle plug 905 also comprises a pair of annular shutters. These represent an upper obturator 912, adjacent to the upper obturator unit 210 ', and a lower obturator 914, adjacent to the lower obturator unit 210 ”. The new combination of the upper obturator unit 210 'with the upper obturator 912, and the lower obturator unit 210 ”with the lower obturator 914, allows the operator to successively isolate a subsurface interval, such as the intermediate interval 114, in a completion of open hole.
[0188] [00188] Another technique for isolating a gap along an open-hole formation is shown in Figure 9B. Figure 9B is a side view of a 900B well. Well 900 B can again be in accordance with well 100 of Figure 2. Here, the lower gap 116 of open hole completion is shown. The lower range 116 extends essentially to the base 136 of the well 900B and is the lowest zone of interest.
[0189] [00189] In this example, subsurface gap 116 may be a part of a subsurface formation that once produced hydrocarbons in commercially viable quantities, but has now undergone significant invasion of water or hydrocarbon gas. Alternatively, the subsurface gap 114 may be a formation that was originally a water or aquitard zone or is otherwise substantially saturated with aqueous fluid. In either example, the operator decided to seal the inflow of formation fluids from the 114 range into well 900A.
[0190] [00190] To accomplish this, a plug 920 was placed inside well 100. Specifically, plug 920 was placed in mandrel 215 supporting the lower filling unit 210 ”. Of the two filling units 210 ’, 210”, only the lower filling unit 210 ”is seen. By positioning the plug 920 in the lower filling unit 210 ”, the plug 920 is able to prevent the flow of formation fluids into well 200 of the lower gap 116.
[0191] [00191] It is noted that, as for the arrangement of Figure 9B, the intermediate gap 114 may comprise a shale or other rock matrix that is substantially impermeable to the flow of fluid. In this situation, buffer 920 does not need to be placed adjacent to the lower filling unit 210 ”, instead, buffer 920 can be placed anywhere above the lower range 116 and along the intermediate range 114. In addition, in this example, the upper shutter unit 210 'does not need to be positioned at the top of the intermediate gap 114; instead, the upper shutter unit 210 'can also be placed anywhere along the intermediate gap 114. If the intermediate gap 114 is comprised of unproductive shale, the operator can choose to place empty tubes through this region with channels of alternative flows, that is, transport tubes, along the intermediate interval 114.
[0192] [00192] A 1000 method for completing a well is also provided here. Method 1000 is shown in Figure 10. Figure 10 provides a flowchart showing steps for a 1000 method of completing a well, in various embodiments. Preferably, the well is an open-hole well.
[0193] [00193] Method 1000 includes providing a zonal isolation device. This is shown in Table 1010 of Figure 10. The zone isolation apparatus is preferably in accordance with the components described above in relation to Figure 2. In this regard, the zone isolation apparatus may first include a sand sieve. The sand sieve will represent a base tube and a surrounding mesh or coiled wire. The zone isolation device will also have at least one shutter unit. The obturator unit will have at least one mechanically placed obturator, with the mechanically placed obturator having alternative flow channels.
[0194] [00194] Preferably, the obturator unit will have at least two mechanically placed shutters. Alternative flow channels will travel through each of the mechanically placed shutters. Preferably, the zonal isolation apparatus will comprise at least two blanking units separated by sand sieve joints or virgin joints or some combination thereof.
[0195] [00195] Method 1000 also includes introducing the zonal isolation device into the well. The step of introducing the zonal isolation device into the well is shown in Table 1020. The zonal isolation device is inserted into a lower part of the well, which is preferably completed with an open-hole.
[0196] [00196] The open-hole part of the well can be completed substantially vertically. Alternatively, the hole-open part can be deflected, or even horizontal.
[0197] [00197] Method 1000 also includes positioning the zonal isolation device in the well. This is shown in Figure 10 of Table 1030. The step of positioning the zonal isolation apparatus is preferably done by hanging the zonal isolation apparatus from a lower part of a column of production liners. The device is positioned so that the sand screen is adjacent to one or more selected production intervals along the hole-open part of the well. In addition, a first, from at least one obturator unit, is positioned above or near the top of a selected subsurface range.
[0198] [00198] In one embodiment, the well passes through three separate intervals. These include an upper range, in which hydrocarbons are produced, and a lower range, in which hydrocarbons are no longer being produced in economically viable volumes. Such gaps can be formed from a sand matrix or other permeable rock. The ranges may also include an intermediate range, in which hydrocarbons are not produced. The formation along the intermediate interval can be formed from shale or other substantially impermeable material. The operator can choose to position the first, of at least one obturator unit, near the top of the lower range or anywhere along the intermediate non-permeable range.
[0199] [00199] In one aspect, at least one obturator unit is placed near the top of an intermediate range. Optionally, a second shutter unit is positioned close to the base of a selected range, such as the intermediate range. This is shown in Table 1035.
[0200] [00200] The following method 1000 includes adjusting the sealing elements mechanically placed in each of the at least one sealing unit. This is provided in Table 1040. Mechanically placing the upper and lower elements means that an elastomeric sealing member (or other) fits into the surrounding well wall. The shutter elements isolate an annular region formed between the sand sieves and the formation of surrounding subsurface above and below the shutter units.
[0201] [00201] Beneficially, the step of placing the obturator of Box 1340 is provided before the sludge is injected into the annular region. Placing the plug provides a hydraulic and mechanical seal in the well before any gravel is placed around the elastomeric element. This provides a better seal during the gravel packing operation.
[0202] [00202] The step in Table 1040 can be performed using the shutter 600 of Figures 6A and 6B. The mechanically placed, open-hole 600 plug allows gravel pack completions to gain current flexibility in independent sieve (SAL) applications, providing future zonal isolation of unwanted fluids while enjoying the reliability benefits of a gravel pack completion alternative route.
[0203] [00203] Figure 11 is a flowchart that provides steps that can be employed, in one embodiment, for method 1100 of placing a obturator. Method 110 first includes providing the plug. This is shown in Table 1110. The shutter can be according to the shutter 600 of Figures 6A and 6B. Thus, the obturator is a mechanically placed obturator, which is placed against an open-hole well to seal an annular crown.
[0204] [00204] Fundamentally, the plug will have an internal mandrel, and alternative flow channels around the internal mandrel. The plug can also have a movable piston enclosure and an elastomeric sealing element. The sealing element is operatively connected to the piston enclosure. This means that the sliding of the movable piston enclosure along the plug (in relation to the internal mandrel) will activate the sealing element in engagement with the surrounding well.
[0205] [00205] The plug can also have a hole. The orifice is in fluid communication with the piston housing. The hydrostatic pressure inside the well communicates with the orifice. This, in turn, applies fluid pressure to the piston enclosure. The movement of the piston enclosure along the plug, in response to hydrostatic pressure, causes the elastomeric sealing element to be expanded into fit with the surrounding well.
[0206] [00206] It is preferred that the shutter also has a centralization system. An example is the centralizer 660 of Figures 6A and 6B. It is also preferred that the mechanical force used to drive the sealing element is applied by the piston enclosure through the centralization system. In this way, both the centralizers and the sealing element are placed using the same hydrostatic force.
[0207] [00207] Method 1100 also includes connecting the plug to a tubular body. This is provided in Table 1120. The tubular body can be a blank tube or a downhole measurement tool equipped with alternative flow channels. However, it is preferred that the tubular body is a sand sieve equipped with alternative flow channels.
[0208] [00208] Preferably, the plug is one of two mechanically placed shutters having cup-like sealing elements. The filling unit is placed inside a column of sand sieves or empty spaces equipped with alternative flow channels.
[0209] [00209] Regardless of the arrangement, method 1100 also includes introducing the plug and the tubular body connected into a well. This is shown in Table 1130. In addition, method 1100 includes introducing a placement tool into the well. This is provided in Table 1140. Preferably, the connected plug and sand sieve are introduced first, followed by the placement tool. The placement tool can be according to the exemplary placement tool 750 of Figure 7C. Preferably, the placement tool is part of or is introduced with a wash tube.
[0210] [00210] Method 1100 then includes moving the placement tool through the internal mandrel of the plug. This is shown in Table 1150. The placement tool is moved into the well using mechanical force. Preferably, the placement tool is at the end of a working column, such as coiled tubing.
[0211] [00211] The movement of the insertion tool through the internal mandrel causes the insertion tool to move the sleeve along the internal mandrel. In one aspect, shifting the sleeve will shear one or more shear pins. In either respect, moving the sleeve releases the piston housing, allowing the piston housing to shift or slide along the plug relative to the internal mandrel. As noted above, this movement of the piston enclosure allows the sealing element to be actuated against the wall of the surrounding borehole.
[0212] [00212] Regarding the movement step of Table 1150, method 1100 also includes transmitting hydrostatic pressure to the orifice. This is seen in Table 1160. Transmitting hydrostatic pressure means that the well has enough energy stored in a fluid column to create a hydrostatic drop, where the hydrostatic drop acts against a surface or shoulder in the piston enclosure. Hydrostatic pressure includes the pressure of fluids in the well, whether such fluids are completion fluids or reservoir fluids. Because the shear pins (including setting screws) are sheared, the piston enclosure is free to move.
[0213] [00213] Returning again to Figure 10, method 1000 for completing an open-hole well also includes injecting particulate sludge into the annular region. This is shown in Table 1050. The particulate sludge is composed of a carrier fluid and particles of sand (and / or others). One or more alternative flow channels allow the particulate sludge to bypass the sealing elements of the mechanically placed shutters. In this way, the open-hole part of the well is gravel packed below, or above and below (but not between), the mechanically placed filling elements.
[0214] [00214] Note that the packing sequence of the annular crown may vary. For example, if a premature sand bridge is formed during the packing of gravel, the annular crown above the bridge will continue to be packed with gravel, via leakage of fluid through the sand sieve, due to the alternative flow channels. In this regard, some mud will flow into and through alternative flow channels to bypass the premature sand bridge and deposit a pack of gravel. When the annular crown above the premature sand bridge is almost completely packed, the sludge is increasingly deflected into and through alternative flow channels. Here, both the premature sand bridge and the plug will be deflected, so that the annular crown is packed with gravel under the plug.
[0215] [00215] It is also possible that a bridge of premature sand could form under the shutter. Any voids above or below the obturator will eventually be packed through the alternate flow channels, until the entire annular crown is completely packed with gravel.
[0216] [00216] During pumping operations, once the gravel covers the sieves above the plug, the sludge is diverted into the bypass tubes, then passes through the plug and continues to pack below the plug, via the bypass tubes ( or alternative flow channels), with side holes allowing the sludge to escape into the annular crown of the well. The hardware provides the ability to seal the bottom water, selectively complete or pack the target intervals with gravel, perform a stacked open hole completion, or isolate a sand containing gas / water after production. The hardware also allows to take into account the selective stimulus, selective water or gas injection or selective chemical treatment to remove damage or consolidate the sand.
[0217] [00217] Method 1000 also includes producing production fluids at intervals along the open-hole part of the well. This is provided in Table 1060. Production takes place over a period of time.
[0218] [00218] In an embodiment of method 1000, the flow of a selected interval can be prevented from flowing into the well. For example, a plug can be installed in the base tube of the sand sieve above or near the top of a selected subsurface range. This is shown in Table 1070. Such a plug can be used at or below the lower obturator unit, such as the second obturator unit of step 1035.
[0219] [00219] In another example, a straddle plug is placed along the base tube along a selected subsurface interval to be sealed. This is shown in Table 1075. Such a stranding may involve placing sealing elements adjacent to the upper and lower sealing units (such as 210 ’, 210” sealing units in Figure 2 or Figure 9A) along a mandrel.
[0220] [00220] Other embodiments of sand control devices 200 can be used with the apparatus and methods here. For example, sand control devices can include independent screens (SAS), pre-packaged screens, or membrane screens. Joints can be any combination of sieve, blank tube or zonal isolation device.
[0221] [00221] The downhole plug can be used to isolate formation in contexts other than production. For example, the method may further comprise injecting a solution from a terrestrial surface, through the internal mandrel downward from the obturator, and into a subsurface formation. The solution can be, for example, an aqueous solution, an acidic solution, or a chemical treatment. The method can then further comprise circulating the aqueous solution, the acidic solution, or the chemical treatment, to unblock an area of the well along the hole-open part of the well. This can be done before or after production operations begin. Alternatively, the solution may be an aqueous solution and the method may further comprise continuing to inject the aqueous solution into the subsurface formation as part of an improved oil recovery operation.
[0222] [00222] Although it is evident that the inventions described here are well calculated to obtain the benefits and advantages explained above, we observe that the inventions are susceptible to modification, variation and change, without deviating from their spirit. Improved methods for completing an open-hole well 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 within a selected subsurface range.

权利要求:
Claims (15)
[0001]
Method for completing a well (105) in a subsurface formation, said method characterized by the fact that it comprises: provide a shutter, the shutter comprising: an internal mandrel (610), alternative flow channels along the inner mandrel (610), a movable piston housing (640) (620) retained around the inner mandrel (610); one or more flow holes (628) providing fluid communication between alternative flow channels and a pressure bearing surface (642) of the piston housing (640), and a sealing element (655) external to the internal mandrel (610); connect the plug to a tubular body insert the plug and tubular body connected into the well (105); insert a placement tool (750) into the inner mandrel (610) of the plug; manipulate the placement tool (750) to mechanically release the movable piston housing (640) (620) from its held position; adjust the plug by transmitting hydrostatic pressure to the piston housing (640) through one or more flow holes (628), thereby moving the released piston housing (640) to drive the sealing element (655) against the well (105 ) surrounding; injecting a gravel sludge into an annular region formed between the tubular body and the surrounding well (105); and inject the gravel sludge through alternative flow channels, to allow the gravel sludge to at least partially deviate from the sealing element (655), so that the well (105) is packed with gravel within an annular region under the shutter.
[0002]
Method according to claim 1, characterized by the fact that: the well (105) has a lower end defining an open-hole part (120); the plug and the tubular body are introduced into the well (105) along the hole-open part (120); the plug is placed inside the hole-open part (120) of the well (105); the tubular body is (i) a sand sieve (200) comprising a base tube, alternative flow channels, and a surrounding filter medium, or (ii) a blank tube having alternative flow channels; and the base tube or the blank tube is composed of a plurality of joints.
[0003]
Method according to claim 2, characterized by the fact that the filling unit (300) comprises: the first mechanically placed shutter; and a second mechanically placed shutter away from the first mechanically placed shutter, the second mechanically placed shutter being substantially a mirror image of or substantially identical to the first mechanically placed shutter.
[0004]
Method according to claim 3, characterized by the fact that each of the first and second shutters still comprises: a movable piston housing (640) (620) retained around the inner mandrel (610); and one or more flow holes (628) providing fluid communication between alternative flow channels and a pressure bearing surface (642) in the piston housing (640).
[0005]
Method according to claim 4, characterized by the fact that it further comprises: insert a placement tool (750) into the internal mandrel (610) of each of the shutters; manipulating the placement tool (750) to mechanically release the movable piston housing (640) from its retained position along each of the respective first and second shutters; and transmit hydrostatic pressure to the piston enclosures through one or more flow holes (628), thereby moving the released piston enclosures and activating the sealing element (655) of each of the first and second shutters against the well (105 ) surrounding.
[0006]
Method according to claim 5, characterized by the fact that: introducing the placement tool (750) comprises inserting a washing tube into a hole within the internal mandrels of the respective first and second shutters, the washing tube having the placement tool (750) in it; and releasing the movable piston enclosure (640) from its retained position comprises pulling the flushing tube with the placement tool (750) along the internal mandrels of the respective first and second plugs, thereby displacing the release sleeves in each of the first and second shutters, and shearing the respective shear pins (720).
[0007]
Method according to claim 2, characterized by the fact that it still comprises: produce hydrocarbon fluids of at least one gap along the open-hole part (120) of the well (105).
[0008]
Method according to claim 2, characterized by the fact that: the shutter further comprises a centralizer (660); and adjusting the shutter also comprises operating the centralizer (660) in the socket with the hole-open part (120) surrounding the well (105).
[0009]
Method according to claim 1, characterized in that the step of injecting the gravel sludge through the alternative flow channels comprises diverting the sealing element (655), so that the hole-open part (120) of the well (105) is packed with gravel above and below the plug after the plug has been placed inside the well (105).
[0010]
Method according to claim 1, characterized by the fact that: the plug further comprises a release sleeve (710) along an internal surface of the internal mandrel (610); and manipulating the insertion tool (750) comprises pulling the insertion tool (750) through the internal mandrel (610) to move the release sleeve (710).
[0011]
Method according to claim 10, characterized by the fact that moving the release sleeve (710) shears at least one shear pin.
[0012]
Method according to claim 11, characterized by the fact that: introducing the placement tool (750) comprises introducing a wash tube into a hole within the inner mandrel (610) of the plug, the wash tube having the placement tool (750) in it; and releasing the movable piston housing (640) from its retained position comprises pulling the flushing tube with the placement tool (750) along an internal mandrel (610), thereby displacing the release sleeve (710) and shearing the at least one shear pin.
[0013]
Method according to claim 12, characterized in that the sealing element (655) is an elastomeric cup-like element.
[0014]
Method according to claim 12, characterized by the fact that: the shutter further comprises a centralizer (660); and releasing the piston enclosure (640) still activates the centralizer (660) in the socket with the hole-open part (120) surrounding the well (105).
[0015]
Method according to claim 14, characterized in that the transmission of hydrostatic pressure to the piston enclosure (640) moves the piston enclosure (640) to activate the centralizer (660), which, in turn, activates the sealing element (655) against the surrounding well (105).

类似技术:

---

公开号 | 公开日 | 专利标题

---

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

---

BR112013013147B1|2020-07-21|well apparatus and methods for multi-zone well completion, production and injection

---

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

---

BR112012010292B1|2019-09-17|ZONAL INSULATION WRAPPING PACKAGE

---

AU2011341559B2|2016-08-11|Crossover joint for connecting eccentric flow paths to concentric flow paths

---

US9638012B2|2017-05-02|Wellbore apparatus and method for sand control using gravel reserve

---

US9670756B2|2017-06-06|Wellbore apparatus and method for sand control using gravel reserve

---

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

---

OA17382A|2016-09-29|Wellbore apparatus and method for sand control using gravel reserve.

---

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

同族专利:

---

公开号 | 公开日

---

EP3431703A1|2019-01-23|

---

AU2011341561B2|2016-07-21|

---

BR112013013146A2|2016-08-23|

---

EA201390897A1|2014-04-30|

---

EP2652244A2|2013-10-23|

---

CA2819350A1|2012-06-21|

---

EP2652244B1|2019-02-20|

---

WO2012082303A3|2013-10-17|

---

SG190863A1|2013-07-31|

---

EA025810B1|2017-01-30|

---

US9404348B2|2016-08-02|

---

MX349183B|2017-07-17|

---

MX2013006301A|2013-07-02|

---

CN103797211B|2016-12-14|

---

US20130248179A1|2013-09-26|

---

EP3431703B1|2020-05-27|

---

MY166117A|2018-05-24|

---

EP2652244A4|2017-12-20|

---

WO2012082303A2|2012-06-21|

---

AU2011341561A1|2013-07-04|

---

SG10201510411TA|2016-01-28|

---

CA2819350C|2017-05-23|

---

CN103797211A|2014-05-14|

引用文献:

---

公开号 | 申请日 | 公开日 | 申请人 | 专利标题

---

---

US3731740A|1971-05-24|1973-05-08|Dresser Ind|Floating piston for selective hydraulic packer|

---

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

---

GB2218442B|1988-05-10|1992-08-26|Texas Iron Works|Retrievable well bore packer with landing nipple|

---

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|

---

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|

---

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|

---

US6244351B1|1999-01-11|2001-06-12|Schlumberger Technology Corporation|Pressure-controlled actuating mechanism|

---

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|

---

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|

---

CA2511826C|2002-12-26|2008-07-22|Baker Hughes Incorporated|Alternative packer setting method|

---

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|

---

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

---

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

---

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|

---

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|

---

CN201152161Y|2007-11-14|2008-11-19|辽河石油勘探局|Outer pipe packer for cementing absorption well|

---

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|

---

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|

---

US8783348B2|2010-12-29|2014-07-22|Baker Hughes Incorporated|Secondary flow path module, gravel packing system including the same, and method of assembly thereof|

---

US9157300B2|2011-01-19|2015-10-13|Baker Hughes Incorporated|System and method for controlling formation fluid particulates|

---

US9353604B2|2012-07-12|2016-05-31|Schlumberger Technology Corporation|Single trip gravel pack system and method|

---

BR112015006970A2|2012-10-26|2017-07-04|Exxonmobil Upstream Res Co|equipment and method for sand control well drilling using gravel reserves|

---

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

---

US9394765B2|2012-12-07|2016-07-19|Halliburton Energy Services, Inc.|Gravel packing apparatus having locking jumper tubes|

---

US9638011B2|2013-08-07|2017-05-02|Schlumberger Technology Corporation|System and method for actuating downhole packers|

---

US10233746B2|2013-09-11|2019-03-19|Baker Hughes, A Ge Company, Llc|Wellbore completion for methane hydrate production with real time feedback of borehole integrity using fiber optic cable|

---

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

---

WO2015038265A2|2013-09-16|2015-03-19|Exxonmobil Upstream Research Company|Downhole sand control assembly with flow control, and method for completing a wellbore|

---

US9416639B2|2014-01-13|2016-08-16|Harris Corporation|Combined RF heating and gas lift for a hydrocarbon resource recovery apparatus and associated methods|

---

US9376900B2|2014-01-13|2016-06-28|Harris Corporation|Combined RF heating and pump lift for a hydrocarbon resource recovery apparatus and associated methods|

---

CA2933629C|2014-02-10|2018-05-01|Halliburton Energy Services, Inc.|Simultaneous injection and production well system|

---

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

---

CN103982153B|2014-05-30|2017-02-08|四机赛瓦石油钻采设备有限公司|Ball injecting de-blocking hydraulic tubing anchor|

---

WO2016195720A1|2015-06-05|2016-12-08|Halliburton Energy Services, Inc.|Completion system for gravel packing with zonal isolation|

---

US10563475B2|2015-06-11|2020-02-18|Saudi Arabian Oil Company|Sealing a portion of a wellbore|

---

US9650859B2|2015-06-11|2017-05-16|Saudi Arabian Oil Company|Sealing a portion of a wellbore|

---

US9482062B1|2015-06-11|2016-11-01|Saudi Arabian Oil Company|Positioning a tubular member in a wellbore|

---

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

---

US10577906B2|2018-02-12|2020-03-03|Eagle Technology, Llc|Hydrocarbon resource recovery system and RF antenna assembly with thermal expansion device and related methods|

---

US10767459B2|2018-02-12|2020-09-08|Eagle Technology, Llc|Hydrocarbon resource recovery system and component with pressure housing and related methods|

---

US10502041B2|2018-02-12|2019-12-10|Eagle Technology, Llc|Method for operating RF source and related hydrocarbon resource recovery systems|

---

US10577905B2|2018-02-12|2020-03-03|Eagle Technology, Llc|Hydrocarbon resource recovery system and RF antenna assembly with latching inner conductor and related methods|

---

US10151187B1|2018-02-12|2018-12-11|Eagle Technology, Llc|Hydrocarbon resource recovery system with transverse solvent injectors and related methods|

---

RU2700606C1|2018-07-23|2019-09-18|Общество с ограниченной ответственностью холдинговая компания "ПЕТРОГАЗТЕХ" |RUBBER MIXTURE FOR A PACKER DEVICE CUFF, WHICH SWELLS IN AN AQUEOUS SOLUTION OF NaCl OR CaCl2 WITH CONCENTRATION OF NOT MORE THAN 25 %|

---

GB2594381A|2018-12-13|2021-10-27|Schlumberger Technology Bv|Gravel pack sleeve|

---

GB2595147A|2019-02-20|2021-11-17|Schlumberger Technology Bv|Gravel packing leak off system positioned across non-perforated coupling region|

---

CN110617202B|2019-10-12|2021-12-07|克拉玛依胜利高原机械有限公司|Bridge type injection and suction sand-proof pump|

---

CN112177558B|2020-10-13|2021-06-25|中国矿业大学|Novel underground coal gasification exploitation process leakage plugging device|

---

CN111927379B|2020-10-14|2020-12-15|东营市瑞丰石油技术发展有限责任公司|Bypass packer|

---

CN113153207A|2021-06-11|2021-07-23|西南石油大学|Packer driven by gas and packer setting method|

法律状态:
2018-12-18| B06F| Objections, documents and/or translations needed after an examination request according art. 34 industrial property law|

---

2019-08-20| B06U| Preliminary requirement: requests with searches performed by other patent offices: suspension of the patent application procedure|

---

2020-02-11| B06A| Notification to applicant to reply to the report for non-patentability or inadequacy of the application according art. 36 industrial patent law|

---

2020-05-19| B09A| Decision: intention to grant|

---

2020-07-21| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 17/11/2011, 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|

---

PCT/US2011/061223|WO2012082303A2|2010-12-17|2011-11-17|Packer for alternate flow channel gravel packing and method for completing a wellbore|

---