well apparatus and methods for multi-zone well completion, production and injection

专利摘要:
WELL APPLIANCE AND METHOD FOR COMPLETING, PRODUCTION AND INJECTION OF MULTI-ZONE WELLS. The completion of a well in a subsurface formation with filling units, having the first mechanically-adjusted plug as the first zonal insulation tool and the second zonal insulation tool, comprises an internal hole to receive production fluids and alternative flow channels. The first plug has alternative flow channels around the inner mandrel and sealing element external to the inner mandrel and includes a obturator unit operatively connecting to a sand sieve, and running into the well. The first obturator set activating the sealing element to fit with the hole-open part surrounding the well. Then, inject a gravel sludge and still inject the gravel sludge through alternative flow channels, to allow it to bypass the sealing element, resulting in a gravel-dense well within an annular region between the sand sieve and the surrounding formation under the obturator unit.
公开号:BR112013013147B1
申请号:R112013013147-0
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 and U.S. Provisional Application No. 61 / 549,056, filed on October 19, 2011. 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] This 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 filling. The order also refers to a downhole plug, which can be placed inside a jacketed hole or an open-hole piece and incorporates alternating flow channel technology. DISCUSSION OF TECHNOLOGY
[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 to a predetermined depth, the drill column and drill bit 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. 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 "squeeze" 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 casing tubes, referred to as the production liner, 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, e.g. 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 usually 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 like 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 reduction range or an interval having an enlarged or irregular borehole, poor gravel distribution can occur due to premature loss of gravel slurry transport fluid 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] The problems of sand bridge formation and deviation from zonal isolation 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 fluid diversion technology is described, for example, in U.S. Pat. US No. 5,588,487, entitled “Tool for Blocking Axial Flow en Gravel-Packed Well Annulus” and PCT Publication No. W02008 / 060479, entitled “Wellbore Method and Apparatus for Completion, Production and Injection”, each of which is incorporated here by reference in its entirety. Additional references that discuss alternative flow channel technology include U.S. Patent No. 4,947,991; U.S. Patent No. 5,113,935; U.S. Patent No. 7,661,476; and M.D. Barry, et al., “Open-hole Gravel Packing with Zonal Isolation”, Document SPE 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 with open-hole completions, to isolate the 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 native water zones, formation of cones (elevation of the water-hydrocarbon contact near the well), high permeability veins, natural fractures or infiltration of the injection wells. Depending on the mechanism or cause of water production, water can be produced at different locations and times during the life of a well. Similarly, a gas cover above an oil reservoir can expand and advance, causing oil to produce gas. The advance of the gas reduces the activation of the gas cover 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 allocation of production, control of the production / injection fluid profile, selective stimulation or control of water or gas. However, the design and installation of open-hole plugs is highly problematic due to stretched areas, undermining areas, higher pressure differentials, frequent pressure cycling and irregular drill hole 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.
[0018] [0018] Therefore, there is a need for an improved sand control system, which provides fluid 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
[0019] [0019] A gravel pack zonal isolation device for a well is first provided here. The zonal isolation device is particularly useful with regard to placing a gravel package inside a hole-open part of the well. The open-hole part extends through one, two or more subsurface intervals.
[0020] [0020] In one embodiment, the zonal isolation apparatus first includes a sand control device. The sand control device includes a base tube. The base tube defines a tubular member having a first end and a second end. Preferably, the zonal isolation apparatus further comprises a filtering medium surrounding the base tube along a substantial part of the base tube. Together, the base tube and the filter medium form a sand sieve.
[0021] [0021] The sand sieve is arranged to have alternative flow path technology. In this regard, the sand sieve includes at least one alternative flow channel to bypass the base tube. The channels extend from the first end to the second end.
[0022] [0022] The zone isolation device also includes at least one and, optionally, at least two obturator units. Each shutter unit comprises at least two mechanically placed shutters. These represent an upper shutter element and a lower shutter element. The top and bottom shutter elements can be from about 6 inches (15.2 cm) to 24 inches (61.0 cm) in length.
[0023] [0023] Intermediate with at least two mechanically placed shutters, there is at least one expandable obturator element. The expandable closure element is preferably about 3 feet (0.91 meters) to 40 feet (12.2 meters) in length. In one aspect, the expandable closure element is made of an elastomeric material. The expandable plug element is activated during time in the presence of a fluid, such as water, gas, oil or a chemical. Expansion can occur, for example, if one of the mechanically placed closure elements fails. Alternatively, swelling may occur during the time when the formation fluids, surrounding the swellable plug element, contact the swellable plug element.
[0024] [0024] The expandable filling element preferably expands in the presence of an aqueous fluid. In one aspect, the expandable filling element may include an elastomeric material that swells in the presence of hydrocarbon liquids or an active chemical. This can be in place of or in addition to an elastomeric material that swells in the presence of an aqueous fluid.
[0025] [0025] The zone isolation device also includes one or more alternative flow channels. Alternative flow channels are arranged outside the base tube and along the various closure elements within each closure unit. Alternative flow channels serve to divert the gravel packet sludge from an upper range to one or more lower intervals during a gravel packing operation.
[0026] [0026] In one embodiment, the elongated base tube comprises multiple tube joints connected end to end to form the first end of the sand control device and a second end of the sand control device. The zonal isolation apparatus can then comprise an upper shutter unit, placed at the first end of the sand control device, and a lower shutter unit, placed at the second end of the sand control device. The upper obturator unit and the upper obturator unit are spaced apart along the pipe joints in order to straddle a selected subsurface interval within a well.
[0027] [0027] The first and second mechanically placed shutters are nically designed to be placed inside the open-hole part of the well before a gravel packing operation begins. For this purpose, a specially designed downhole operations is offered here, which can be used with the filling unit and methods here. The downhole plug seals an annular region between a tubular body and a surrounding well. The well may be a jacketed hole, meaning that a column of production liners has been drilled. Alternatively, the well can be completed as an open hole.
[0028] [0028] In one embodiment, each downhole plug comprises an internal mandrel, at least one alternative flow channel along the internal mandrel and a sealing element external to the internal mandrel. The sealing element resides circumferentially around the inner mandrel.
[0029] [0029] Each downhole plug can also include a movable piston enclosure. The piston housing is initially fixed 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 activates the sealing element to fit with the surrounding open-hole well.
[0030] [0030] Preferably, each plug also 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 beneficially serves as the at least one alternative flow channel.
[0031] [0031] Each plug can also include one or more flow 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.
[0032] [0032] In one embodiment, each downhole plug also includes a release sleeve. The release sleeve resides along the inner surface of the inner mandrel. In addition, each shutter includes a release key. The release switch is connected to the release sleeve. The sleeve wrench is movable between a holding position, in which the release wrench engages and holds the movable piston housing in position, and a release position, in which the release wrench disengages from the piston housing. When disengaged, the hydrostatic pressure acts against the pressure bearing surface of the piston enclosure and moves the piston enclosure along the inner mandrel to drive the sealing element.
[0033] [0033] In one aspect, each shutter 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. Thus, each shutter is a mechanically adjusted shutter.
[0034] [0034] In one embodiment, each downhole plug also has a centralizer. The centralizer has extensible fingers. The fingers extend radially in response to the movement of the piston enclosure. The centralizer is arranged around the internal mandrel between the piston housing and the sealing element. The downhole plug is preferably configured so that the force applied by the piston enclosure against the centralizer also activates the sealing element against the surrounding well.
[0035] [0035] A method for completing a well in a subsurface formation is also provided here. The well preferably includes a bottom part completed as an open-hole. In one aspect, the method includes providing a shutter. The shutter can be according to the mechanically-adjusted 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 element is preferably an elastomer cup-type element.
[0036] [0036] The method also includes connecting the plug with a sand sieve and then running the plug and the connected sand sieve into the well. The connected plug and sand sieve are placed along the open-hole (or other production interval) part of the well.
[0037] [0037] The sand sieve comprises a base tube and a surrounding filter medium. The base tube can be made of a plurality of joints. The plug can be connected between two of the plurality of joints of the base tube. Alternatively, the plug can be placed between a sand sieve joint and an expandable plug element.
[0038] [0038] The method also includes adjusting the shutter. This is done by activating the sealing element of the plug to fit with the hole-open part surrounding the well. Next, the method includes injecting a gravel slurry into an annular region formed between the sand sieve and the open-hole part surrounding the well and then injecting the gravel sludge through the alternative flow channels, to allow the gravel mud to deviate from the shutter. In this way, the open-hole part of the well is filled with gravel and under the plug after the plug has been placed in the well.
[0039] [0039] In the method, it is preferred that the obturator is a first mechanically adjusted obturator, which is part of a obturator unit. In this example, the first mechanically-adjusted shutter is a first zone isolation tool and is part of a shutter unit that includes a second zone isolation tool. The second zonal isolation tool can be a second mechanically adjusted plug, which is constructed in accordance with the first mechanically adjusted plug. Alternatively, the second zonal isolation tool can be a gravel-based zonal isolation tool. Alternatively or in addition, the second zonal insulation tool may comprise an expandable plug, intermediate to the first and second mechanically-adjusted shutters. The expandable plug has alternative flow channels, aligned with the alternative flow channels of the first and second mechanically-adjusted shutters.
[0040] [0040] The step of still injecting the gravel sludge through the alternative flow channels allows the gravel sludge to deviate from the filling unit, so that the hole-open part of the well is filled with gravel above and below the shutter unit, after the first and second mechanically-adjusted shutters have been placed inside the well.
[0041] [0041] The method can also include running a placement tool inside the internal mandrel of the shutters, and releasing the movable piston enclosure of each plug from its fixed position. The method then includes applying hydrostatic pressure to the piston enclosure through one or more flow holes. The application of hydrostatic pressure moves the released piston enclosure and activates the sealing element against the surrounding well.
[0042] [0042] It is preferred that the laying tool is part of a washing tube used for packing gravel. In this example, running the placement tool comprises running a flushing tube into a hole within the inner mandrel of the plug, with the flushing tube having a placement tool in it. The step of releasing the movable piston enclosure from its fixed position then comprises pulling the wash tube with the placement tool along the inner mandrel of each plug. This serves to optionally shear a shear pin and move the release sleeves in the respective shutters.
[0043] [0043] The method may also include producing hydrocarbon fluids of at least one gap along the open-hole portion of the well.
[0044] [0044] An alternative method for completing a well is also provided here. The well again has a lower end defining a hole-open part. In one aspect, the method includes running a gravel pack zonal isolation device into the well. The zone isolation apparatus is generally in accordance with the zone isolation apparatus described above in its various embodiments. The zone isolation device will include the intermediate expandable obturator element.
[0045] [0045] Then, the zone isolation device is suspended in the well. The apparatus is positioned so that one of at least one filling unit is positioned above or near the top of a selected subsurface range. Alternatively, the at least one filling unit is positioned close to the interface of two adjacent subsurface intervals. Then, the shutters mechanically placed in each of the at least one shutter unit are placed. This means that the sealing elements of the mechanically placed filling elements are actuated to fit with the open-hole part surrounding the well.
[0046] [0046] The method also includes injecting a particulate slurry into an annular region formed between the sand sieve and the formation of the surrounding subsurface. Particulate sludge is commonly composed of a carrier fluid and particles of sand (and / or others). The one or more alternative flow channels of the zonal isolation apparatus allow the particulate sludge to travel through or around the mechanically placed shutter elements and the intermediate expandable shutter element. In this way, the hole-open part of the well is compacted with gravel above and below (but not between) the mechanically placed filling elements. In addition, the gravel can be placed along the borehole well after mechanically placed shutters have been placed.
[0047] [0047] In one embodiment, the method includes running a placement tool inside the inner mandrel of the first and second mechanically placed shutters and moving the placement tool along the inner mandrels. This frees the movable piston enclosure from each of the first and second mechanically placed shutters. The method then includes applying hydrostatic pressure to the piston enclosure through one or more flow holes. This is used to move the respective piston enclosures and to activate the respective upper and lower sealing elements against the surrounding well.
[0048] [0048] The method also includes producing production fluids from one or more production intervals along the borehole part of the well. Production takes place over a period of time. Over time, the upper obturator, the lower obturator, or both, may fail, allowing fluids to flow into an intermediate portion of the obturator along the expandable obturator element. Alternatively, the intermediate expandable plug can come into contact with the formation fluids or an activating chemical. In either example, contact with fluids will cause the expandable plug element to expand, thereby providing a long-term seal beyond the life of the mechanically placed shutters.
[0049] [0049] Additional steps can be taken for isolated subsurface intervals, along the open-hole part of the well. For example, a straddle plug can be placed inside the base tube of the sand sieve joints over an intermediate interval. The straddle shutter straddles the shutter units placed close to the upper and lower forming interfaces for the intermediate range. In this way, the formation fluids of the intermediate interval are prevented from entering the well.
[0050] [0050] Alternatively, a plug can be placed inside the base tube of the sand sieve joints over a lower gap. The plug is placed at the same depth as a filling unit near the top of the lower range. In this way, the formation fluids of the lower interval are prevented from entering the well. BRIEF DESCRIPTION OF THE DRAWINGS
[0051] [0051] In order 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.
[0052] [0052] 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.
[0053] [0053] 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.
[0054] [0054] 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, along with an intermediate expandable shutter element.
[0055] [0055] Figure 3B is a cross-sectional view of the filling unit in Figure 3A, taken through lines 3B-3B in Figure 3A. Bypass tubes are seen inside the expandable plug element.
[0056] [0056] Figure 3C is a cross-sectional view of the filling unit of Figure 3A, in an alternative embodiment. In place of the bypass tubes, the transport tubes are seen distributed around the base tube.
[0057] [0057] Figure 4A is a cross-sectional side view of the filling unit of Figure 3A. Here, the sand control devices, or sand sieves, were placed at opposite ends of the filling unit. The sand control devices use external bypass tubes.
[0058] [0058] 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, to provide an alternative flow path for a particulate sludge.
[0059] [0059] 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.
[0060] [0060] 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.
[0061] [0061] Figure 6A is a side view in cross section of one of the mechanically placed shutters in Figure 3A. The mechanically placed shutters are in their insertion position.
[0062] [0062] Figure 6B is a side view in cross section of the mechanically placed plug of Figure 3A. Here, the mechanically placed shutter elements remain in their placed position.
[0063] [0063] 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.
[0064] [0064] 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.
[0065] [0065] 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.
[0066] [0066] 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.
[0067] [0067] 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.
[0068] [0068] Figure 7B is an enlarged view of the release key in Figure 6B. The shear pin was sheared and the release key came out of the inner mandrel.
[0069] [0069] Figure 7C is a perspective view of a placement tool that can be used to join a release sleeve and thereby shear a shear pin into the release key.
[0070] [0070] Figures 8A to 8N show stages of a gravel packing procedure, employing one of the filling units of the present invention, in one embodiment. Alternative flow path channels are provided through the filling elements of the filling unit and through the sand control devices.
[0071] [0071] Figure 80 shows the filling unit and gravel package having been placed in an open-borehole following the completion of the gravel packaging procedure of Figures 8A to 8N.
[0072] [0072] Figure 9A is a cross-sectional view of an intermediate interval of the open hole completion of Figure 2. Here, a straddle plug was placed inside a sand control device through the intermediate interval, to avoid the influx of training fluids.
[0073] [0073] 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 obturator between the intermediate and lower intervals to prevent the flow of fluids from the formation up the well from the lower range.
[0074] [0074] Figures 10A to 10D show a sand screen that can be used as part of a well completion system having alternative flow channels. This sieve uses MazeFloTM technology.
[0075] [0075] Figure 10A provides a side view of a part of a sand sieve arranged along a hole-open part of a well.
[0076] [0076] Figure 10B is a cross-sectional view of the sand sieve in Figure 10A, taken through line 10B-10B in Figure 10A. Alternative flow channels are seen inside the sieve.
[0077] [0077] Figure 10C is another cross-sectional view of the sand sieve in Figure 10A. This view is taken through line 10C-10C in Figure 10A.
[0078] [0078] Figure 10D is a third cross-sectional view of the sand sieve of Figure 10A. This view is taken through line 10C-10D of Figure 10A.
[0079] [0079] Figures 11A to 11G show a sand control device, which can be used as part of a well completion system having alternative flow channels. This device uses a sieve with an inflow control device.
[0080] [0080] Figure 11A provides a side view of a part of the sand control device that can be placed along an open-hole part of a well. The illustrative inflow control device is a choke at one end of the screen. An expandable plug is provided at the other end of the screen for fluid control.
[0081] [0081] Figure 11B is a cross-sectional view of the sand control device of Figure 11A, taken through line B-B of Figure 11 A. Alternative flow channels are seen inside the sieve.
[0082] [0082] Figure 11C is another cross-sectional view of the sand control device of Figure 11 A, taken through line c-C.
[0083] [0083] Figure 11D is a third cross-sectional view of the sand control device, taken through line D-D of Figure 11 A.
[0084] [0084] Figure 11E is yet another cross-sectional view of the sand control device of Figure 11 A, taken through line E-E of Figure 11A.
[0085] [0085] Figure 11F is another side view of the sand control device of Figure 11A. Here, the expandable plug has been activated and blocks the annular flow at one end of the sand sieve.
[0086] [0086] Figure 11G is a cross-sectional view of the sand control device of Figure 11F, taken through line G-G of Figure 11F. The expandable plug is seen to fill an annular region between the base tube and the surrounding sieve.
[0087] [0087] Figure 12 is a flow chart of a method of completing a well, in one embodiment. The method involves placing a plug and installing a gravel pack in the well.
[0088] [0088] Figure 13 is a flowchart showing the steps that can be taken in relation to a method of completing an open-borehole, in an alternative embodiment. The method involves installing a zonal isolation device.
[0089] [0089] Figure 14A is a side view of a gravel packaging unit to provide zonal support insulation. The unit defines a base tube having bypass tubes around it.
[0090] [0090] Figure 14B is a cross-sectional view of the gravel packaging unit of Figure 14A, taken through line B-B of Figure 14A. DETAILED DESCRIPTION OF CERTAIN WAYS OF ACCOMPLISHMENT
[0091] [0091] Definitions
[0092] [0092] As used herein, the term "hydrocarbon" refers to an organic compound that includes mainly, if not exclusively, the elements hydrogen and carbon. Hydrocarbons generally fall into two classes: aliphatic or straight chain hydrocarbons, and cyclic or closed 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.
[0093] [0093] As used here, the term "hydrocarbon fluids" refers to a hydrocarbon or mixtures of hydrocarbons that are gases or liquids. For example, hydrocarbon fluids can include a hydrocarbon or mixtures of hydrocarbons that are gases or liquids under formation conditions, processing conditions or ambient conditions (15 ° C and pressure at 1 atm). Hydrocarbon fluids can include, for example, oil, natural gas, coal bed methane, shale oil, pyrolysis oil, pyrolysis gas, a coal pyrolysis product and other hydrocarbons that are in a gaseous or liquid state.
[0094] [0094] 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.
[0095] [0095] As used here, the term "fluid" refers to gases, liquids and combinations of gases and liquids, as well as combinations of gases and solids, and combinations of liquids and solids.
[0096] [0096] As used here, the term "subsurface" refers to geological strata occurring below the earth's surface.
[0097] [0097] 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.
[0098] [0098] 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 herein, the term “well” (well), when referring to an opening in the formation, can be used interchangeably with the term “well” (wellbore).
[0099] [0099] The term "tubular member" refers to any tube, such as a joint of lining tubes, a part of a lining or a joint.
[0100] [00100] 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. A sand sieve is an example of a sand control device.
[0101] [00101] The term “alternative flow channels” means any collection of distribution pipes and / or bypass pipes that provide fluid communication through or around a tubular well tool to allow a gravel sludge to bypass the tool well or any bridge of premature sand in the annular region and continue the filling of gravel further downstream. Examples of such well tools include (i) a plug having a sealing element, (ii) a sand sieve or cracked tube and (iii) a blank tube, with or without an external protective cover. DESCRIPTION OF SPECIFIC ACHIEVEMENTS
[0102] [00102] 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.
[0103] [00103] 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.
[0104] [00104] 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 well open-hole 120 at a lower end of well 100. Well 100 was formed for the purpose of producing hydrocarbons for commercial sale. A column of production tubes 130 is provided in bore 105 to transport production fluids from the open bore part 120 to the surface 101.
[0105] [00105] Well 100 includes a well tree, shown schematically in 124, Well tree 124 includes a shut-off valve 126. Shut-off valve 126 controls the flow of production fluids from well 100. In addition, a valve subsurface safety valve 132 is provided to block the flow of fluids from production line 130 in the event of a rupture or catastrophic event above subsurface safety valve 132. Well 100 can optionally have a pump (not shown) inside or just above open hole part 120 to artificially lift production fluids from open hole well 120 to well tree 124.
[0106] [00106] 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 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 to the 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 coating tubes employing an expandable liner or liner hanger. It is understood that a column of tubes that does not extend backwards towards the surface (such as column of casing tubes 106) is usually referred to as a "liner".
[0107] [00107] In the illustrative well arrangement of Figure 1, the column of intermediate lining tubes 104 is suspended by the surface 101, while the column of lining tubes 106 is suspended by a lower end of the column of lining tubes 104. additional intermediate liner tubes (not shown) can be employed. The present inventions are not limited to the type of casing arrangement used.
[0108] [00108] 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 is understood that some columns of intermediate liner tubes may not be fully cemented.
[0109] [00109] 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.
[0110] [00110] 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 the borehole 120.
[0111] [00111] 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 the 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 infiltrations of the injection wells. In this example, there is a likelihood that water will invade well 100.
[0112] [00112] Alternatively, the upper 112 and intermediate 114 ranges may contain hydrocarbon fluids that are sought to produce, process and sell, while the lower range 116 may contain some oil together with ever-increasing amounts of water. This may be due to the formation of a cone, which is an elevation of the hydrocarbon water contact near the well. In this example, there is again the possibility that water will invade well 100.
[0113] Alternatively, the upper 112 and lower 116 ranges may be producing hydrocarbon fluids from a sand matrix or other permeable rock, while the intermediate gap 114 may represent a non-permeable shale or otherwise be substantially fluid impervious.
[0114] [00114] In any of these events, it is desirable for the operator to isolate selected intervals. In the first example, the operator will want to isolate the intermediate range 114 from the production column 130 and the upper ranges 112 and lower 116, so that mainly hydrocarbon fluids can be produced through well 100 and to surface 101. In the second example, the The operator will eventually want to isolate the lower range 116 of the production column 130 and the upper range 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 upper range 112 from lower range 116, but there is no need to isolate intermediate range 114. Solutions to these needs in the context of an open-hole completion are provided here and are demonstrated more fully with respect to procedure drawings.
[0115] [00115] 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 particles and other fines. 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 into well 100. These are described more fully below with reference to Figure 2 and Figures 8A a 8N.
[0116] [00116] 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 105 is typically composed of a plurality of tube joints. Base tube 205 (or each tube joint comprising base tube 105) typically has small perforations or slits to allow influx of production fluids.
[0117] [00117] Sand control devices 200 also contain filter media 207 wrapped or otherwise placed radially around base tubes 205. Filter media 207 may be a sand mesh sieve or embedded wire winding. around the base tube 205. Alternatively, the filtration medium of the sand sieve comprises a membrane sieve, an expandable sieve, a sintered metal sieve, a porous medium made of shaped memory polymer (such as that described in US Patent No. 7,926,565), a porous medium packed with fibrous material, or a bed of pre-compacted solid particles. The filtration medium 207 prevents the influx of sand or other particles above a predetermined size into the base pipe 205 and the production pipe 130.
[0118] [00118] In addition to 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 (seen at 202 of Figure 2) between the various sand control devices 200 and a surrounding wall 201 of the borehole part 120 of the well 100.
[0119] [00119] 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, 114 are shown.
[0120] [00120] Concerning 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 and hydraulic handling forces. The obturator units 210 represent an upper obturator 212 and a lower obturator 214. Each obturator 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.
[0121] [00121] 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 load due to the differential pressures of 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.
[0122] [00122] The surface or sealing elements for mechanically placed shutters 212, 214 need only be in the order of inches in order to affect an adequate hydraulic seal. In one aspect, the elements are each 6 inches (15.2 cm) to about 24 inches (61.0 cm) in length.
[0123] [00123] The elements for the shutters 212, 214 are preferably cup-like elements. Cup-like elements are known for use in hole-jacketed 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. In addition, such expandable cup-like elements may not maintain the required pressure differential found throughout the life of production operations, resulting in decreased functionality.
[0124] [00124] It is preferred that the closure elements 212, 214 are able to expand to at least an outer diameter surface of 11 inches (about 28 cm), with no more than an ovality ratio of 1.1 . Elements 212, 214 should preferably be able to handle undermines in an 8-1 / 2 inch (about 21.6 cm) or 9-7 / 8 inch hole-open section. (about 25.1 cm). The preferred cup-like nature of the expandable parts of the closure elements 212, 214 will assist in maintaining at least a temporary seal against the wall 201 of the intermediate gap 114 (or other gap) when the pressure increases during the gravel packing operation.
[0125] [00125] In one embodiment, the cup-like elements need not be liquid-tight, nor should they be estimated to handle multiple pressure and temperature cycles. The cup-like elements need only be designed for use at one time, that is, during the gravel packing process of an open-hole well completion. This is because an intermediate expandable plug element 216 is also preferably provided for long-term sealing.
[0126] [00126] The top 212 and bottom 214 shutters are placed before the gravel pack installation process. As more fully described below, the shutters 212, 214 are preferably placed mechanically by shearing a shear pin and sliding the release sleeve. This, in turn, releases a release key, which then allows the hydrostatic pressure to act down against the piston housing. The piston housing moves downward along an internal mandrel (not shown). The piston enclosure then acts on a centralizer and / or a cup-like packaging element. The centralizer and expandable part of the shutters 212,214 expand against the shaft wall 201. The elements of the upper shutter 212 and lower 214 are expanded to contact the surrounding wall 201 in order to straddle the annular region 202 at a selected depth along the hole-120 completion.
[0127] [00127] 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.
[0128] [00128] As a "support" for the cup-type closure elements within the top 212 and bottom closure elements 214, the closure units 210 ', 210 "each also include an intermediate closure element 216. The intermediate closure element 216 defines a swellable elastomer material, made of synthetic rubber compounds. Suitable examples of expandable materials can be found in Easy Well Solutions' ConstrictorTM or SwelIPackerTM and SwellFix’s E-ZIPTM. The expandable plug 216 can include an expandable polymer or expandable polymeric material, which is known to those skilled in the art and which can be placed by one of a conditioned drilling fluid, a completion fluid, a production fluid, an injection fluid , a stimulation fluid or any combination of them.
[0129] [00129] The expandable plug element 216 is preferably attached to the outer surface of mandrel 215. The expandable plug element 216 is allowed to expand over time when contacted by hydrocarbon fluids, forming water or any chemical described above, which can be used as a driving fluid. When the plug element 216 expands, it forms a fluid seal with the surrounding area, e.g. , range 114. In one aspect, a sealing surface of the expandable obturator element 216 is about 5 feet (1.5 meters) to 50 feet (15.2 meters) in length; and, more preferably, about 3 feet (0.9 meters) to 40 feet (12.2 meters) in length.
[0130] [00130] The expandable plug element 216 must be able to expand into the well wall 201 and provide the required pressure integrity in that expansion ratio. Since the expandable plugs are typically placed in a section of shale that cannot produce hydrocarbon fluids, it is preferable to have a swellable elastomer or other material that can swell in the presence of forming water or a water-based fluid. Examples of materials that swell in the presence of a water-based fluid are bentonite clay and a nitrile-based polymer with incorporated water-absorbing particles.
[0131] [00131] Alternatively, the expandable plug element 216 can be manufactured from a combination of materials that swell in the presence of water and oil, respectively. In other words, the expandable plug element 216 can include two types of expandable elastomers - one for water and one for oil. In this situation, the water-swellable element will swell when exposed to water-based gravel pack fluid or in contact with water from the formation, and the oil-based element will expand when exposed to hydrocarbon production. An example of an elastomeric material that will swell in the presence of a hydrocarbon liquid is an oleophilic polymer that absorbs hydrocarbons within its matrix. The expansion occurs from the absorption of hydrocarbons, which also lubricates and decreases the mechanical strength of the polymer chain when it expands. Ethylene propylene diene monomer rubber (M-class) or EPDM, is an example of such a material.
[0132] [00132] The expandable plug 216 can be manufactured from another expandable material. An example is a format memory polymer. U.S. Patent No. 7,243,732 and U.S. Patent No. 7,392,852 describe the use of such a material for zonal isolation.
[0133] [00133] Mechanically placed plug elements 212, 214 are preferably placed in a water-based gravel pack fluid, which would be deflected around the expandable plug element 216, such as through the bypass tubes (not shown in Figure 2) . If only a swellable hydrocarbon elastomer is used, the expansion of the element may not occur until after the failure of one or another of the mechanically placed closure elements 212, 214.
[0134] [00134] The upper shutters 212 and lower 214 can generally be mirror images of each other, except for the release gloves, which shear the respective shear pins or other locking mechanisms. The unilateral movement of a displacement tool (shown and discussed with respect 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 and discussed in connection with Figures 6A and 6B). A short spacing is preferably provided between the upper 212 and lower 214 shutters.
[0135] [00135] The filling units 210 ’, 210” help to control the fluids produced by the different zones. In this regard, the filling units 210 ’, 210” allow the operator to isolate an interval of production or injection, 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, a non-condensable fluid undesirable, such as hydrogen sulfide.
[0136] [00136] Shutters have historically not been installed when an open-hole gravel package is used because of the difficulty in forming a complete gravel package above and below the obturator. Related patent applications, U.S. Publication Nos. 200/0294128 and 2010/0032158 describe apparatus and methods for packing gravel from an open-hole well after a plug has been placed in a completion interval.
[0137] [00137] Certain technical challenges remained with respect to the methods described in Pub. U.S. Nos. 2009/0294128 and 2010/0032158, particularly with regard to the shutter. Orders say 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 needs to be able to maintain zonal insulation for a period of years, in the presence of high pressures and / or elevated temperatures and / or acidic fluids. As an alternative, orders claim that the plug can be an expandable rubber element that expands in the presence of hydrocarbons, water or other stimuli. However, known swellable elastomers typically require about 30 days or more to fully expand in a fluid sealed fitting with the surrounding rock formation. Therefore, improved shutters and zonal isolation apparatus are offered here.
[0138] [00138] Figure 3A shows an illustrative filling unit 300, providing an alternative flow path for a gravel sludge. The shutter unit 300 is seen in lateral view in cross section. The obturator unit 300 includes several components that can be used to seal an annular crown along the bore 120.
[0139] [00139] 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 have 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 (915.2 meters) in length. Tube joints are typically threaded end-to-end to form well completion system 302 according to length 316.
[0140] [00140] 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 the mechanically placed obturator elements 212 and 124 of Figure 2. The obturators 304 preferably include elastomer-type elements cup, which are less than 1 foot (0.3 meter) long. As described below, the 304 shutters have alternative flow channels, which only allow the 304 shutters to be placed before a gravel sludge is circulated into the well.
[0141] [00141] The obturator unit 300 also optionally includes an expandable plug 308. The expandable plug 308 is according to the expandable plug element 216 of Figure 2. The expandable plug 308 is preferably about 3 feet (0.9 meters) a 40 feet (12.2 meters) in length. Together the mechanically placed shutters 304 and the intermediate expandable plug 308 surround the main body section 302. Alternatively, a short spacing can be provided between the mechanically placed shutters 304 in place of the expandable plug 308.
[0142] [00142] The shutter unit 300 also includes a plurality of bypass tubes. The bypass tubes are shown schematically at 318. The bypass tubes 318 can also be referred to as transport tubes or bridged 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 expandable plug 308. The bypass tubes 318 of the obturator unit 300 are configured to engage in and form a seal with bypass tubes or sand screens connected, as discussed below.
[0143] [00143] The bypass tubes 318 provide an alternative flow path through the mechanically placed shutters 304 and the intermediate expandable plug 308 (or spacing). This makes it possible for the bypass tubes 318 to transport a carrier fluid together with gravel to different intervals 112, 114 and 116 of the open-hole well 120 of the well 100.
[0144] [00144] The shutter unit 300 also includes connection members. These can represent traditional threaded couplings. First, a neck section 306 is provided at a first end of the obturator unit 300. The neck section 306 has external threads to connect 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.
[0145] [00145] The narrow section 306 and the threaded section 310 can be made of steel or alloy steel. The narrow section 306 and the threaded section 310 are each configured to have 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.
[0146] [00146] 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. In Figure 3B, the expandable plug 308 is seen circumferentially arranged around the base tube 302. 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 Central hole 305 receives production fluids during production operations and transports them to production piping 130.
[0147] [00147] Figure 4A shows a side view in cross section of a zonal isolation 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 in the sand control devices 200. The bypass tubes 218 represent packaging tubes that allow the flow of gravel mud between a ring annulus and the tubes 218. Bypass tubes 218 over sand control devices 200 optionally include valves 209 to control the flow of gravel sludge, such as packaging tubes (not shown).
[0148] [00148] Figure 4B provides a side view in cross section of the zonal isolation device 400. Figure 4B is taken along line 4B-4B of Figure 4A. This is cut through one of the sand sieves 200. In Figure 4B, the split or perforated base tube 205 is seen. 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 the production fluids during production operations.
[0149] [00149] 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 sand control devices 200 provide an external embodiment for bypass tubes 218 (or alternative flow channels).
[0150] [00150] The configuration of the bypass tubes 218 is preferably concentric. this is seen in the cross-sectional view of Figure 3B. However, bypass tubes 218 can be eccentrically designed. For example, Figure 2B of US Patent No. 7,661,476 shows an "Prior Art" arrangement for a sand control device in which filling tubes 208a and transport tubes 208b are placed external to base tube 202 and surrounding filter medium 204.
[0151] [00151] In the arrangement of Figures 4A and 4B, the bypass tubes 218 are external to the filtration medium, or external mesh 220. However, 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.
[0152] [00152] Figure 5A shows a side view in cross section of a zonal isolation device 500 in an alternative 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 filter medium 220.
[0153] [00153] Figure 5B provides a side view in cross section of the zonal isolation device 500. Figure 5B is taken along the line B-B of Figure 5A. This is cut through one of the sand sieves 200. In Figure 5B, the base tube provided with slits or perforated 205 is seen again. This is according to the base tube 205 of Figures 1 and 2. The central bore 105 is shown inside the base tube 205 to receive production fluids during production operations.
[0154] [00154] 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.
[0155] [00155] An annular region 225 is created between the base tube 205 and the outer mesh or surrounding filter medium 220. The annular region 225 accommodates the influx of production fluids into a well. The outer wire winding 220 is supported by a plurality of support ribs extending radially 222. The ribs 222 extend through the annular region 225.
[0156] [00156] Figures 4A and 5A present arrangements for connecting the 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. Meanwhile the zonal isolation apparatus arrangements 400, 500 of Figures 4A-4B and 5A -5B are for illustrative purposes only. In an alternative arrangement, a distribution system can be used to provide fluid communication between bypass tubes 218 and bypass tubes 318.
[0157] [00157] 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, provided that mud diversion is provided for the filling unit 210. However, it is preferred that a concentric arrangement is employed.
[0158] [00158] It should also be noted that the coupling mechanism for 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 alternate flow path formed by the bypass tubes. Examples of such sealing mechanisms are described in U.S. Patent No. 6,464,261; Patent Application Intl. WO 2004/094769; Inti Patent Application. WO 2005/031105; U.S. Patent Publication No. 2004/0140089; Publ. U.S. Patent No. 2005/0028977; Publ. Pat. No. 2005/0061501; and Publ. Pat. No. 2005/0082060.
[0159] [00159] The coupling of the sand control devices 200 with a filling unit 300 requires alignment of the bypass tubes 318 of the filling unit 300 with the bypass tubes 218 along the sand control devices 200. In this respect, the path flow of bypass tubes 218 from sand control devices should be non-interrupted when fitting into a shutter. Figure 4A (described above) shows sand control devices 200 connected to an intermediate shutter unit 300, with bypass tubes 218, 318 in alignment. However, making this connection typically requires a special sub or bridge with a union type connection, a regulated connection to align the multiple tubes or a cylindrical cover plate over the connecting tubes. These connections are expensive, time-consuming and / or difficult to handle on the floor of the device.
[0160] [00160] U.S. Patent No. 7,661,476, entitled "Gravel Packing Methods", describes a production column (referred to as a joint unit) that employs one or more sand sieve joints. The sand sieve joints are placed between a “load sleeve unit” and a “torque sleeve unit”. The load sleeve unit defines an elongated body comprising an outer wall (serving as an outer diameter) and an inner wall (providing an inner diameter). The inner wall forms a hole through the load sleeve unit. Similarly, the torque sleeve unit defines an elongated body, comprising an outer wall (serving as an outer diameter) and an inner wall (providing an inner diameter). The inner wall also forms a hole through the torque sleeve unit.
[0161] [00161] The cargo glove unit includes at least one transport conduit and at least one packaging conduit. The at least one transport conduit and the at least one packaging conduit are arranged external to the internal diameter and internal to the external diameter. Similarly, the torque sleeve unit includes at least one conduit. The at least one conduit is also disposed external to the internal diameter and internal to the external diameter.
[0162] [00162] The production column includes a "main body part". This is essentially a base tube that runs through the sand sieve. A coupling unit, having a distribution region, can also be provided. The distribution region is configured to be in fluid flow communication with at least one conveying conduit and at least one packaging conduit of the cargo glove unit during at least a part of the gravel packaging operations. The coupling unit is operably connected to at least part of the at least one joint unit at or near the load sleeve unit. The load sleeve unit and the torque sleeve unit are composed of or coupled with the base tube, in such a way that the transport and packaging ducts are in fluid communication, thereby providing alternative flow channels for gravel sludge . The benefit of the load sleeve unit, the torque sleeve unit and a coupling unit is that they allow a series of sand sieve joints to be connected and run into the well in a faster and less expensive way.
[0163] [00163] As mentioned, the stopper unit 300 includes a pair of mechanically placed stoppers 304. When using the stopper unit 300, the stoppers 304 are beneficially placed before the mud is injected and the gravel packet is formed. This requires a single plug arrangement, in which the bypass tubes are provided for an alternating flow channel.
[0164] [00164] The plugs 304 of Figure 3A are shown schematically. However, Figures 6A and 6B provide more detailed views of a mechanically placed obturator 600, which can be used in the obturator unit of Figure 3A, in one embodiment. The views in Figures 6A and 6B provide lateral views in cross section. In Figure 6A, the shutter 600 is in its insertion position, while in Figure 6B the shutter 60 is in its placed position.
[0165] [00165] 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.
[0166] [00166] 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 production fluids through the obturator 600. After installation and beginning of production, central hole 605 transports production fluids to hole 105 of sand sieves 200 (seen in Figures 4A and 4B) and to production pipe 130 (see in Figures 1 and 2).
[0167] [00167] The plug 600 also includes a first end 602. Threads 604 are placed along inner mandrel 610 at first end 602. Illustrative threads 604 are external threads. A housing connector 614, having internal threads at both ends is connected or screwed into the threads 604 at 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 reading module, a production pipe or a pipe in White.
[0168] [00168] The connector box 614 at the end of the box 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 reading module, a production pipe or a pipe in White.
[0169] [00169] 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 internal diameter near the first end 602. This is due to a machining shoulder 606 machined within the inner mandrel. As will be explained more fully below, the placement shoulder 606 grips a release sleeve 710 in response to the mechanical force applied by a placement tool.
[0170] [00170] The plug 600 also includes a piston mandrel 620. The piston mandrel 620 extends generically 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, which resides circumferentially around 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.
[0171] [00171] 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 configured so that the alternative flow channels are inside the hole 505 of the internal mandrel 610. In one or another example, the alternative flow channels are "along" the internal mandrel 610.
[0172] [00172] The annular ring 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, at the first end, the sand sieves 200 of Figures 4A and 5A, or a blank tube, an expandable zonal isolation plug, such as plug 308 of Figure 3A, or another tubular body. The tubular body may or may not have alternative flow channels.
[0173] [00173] Plug 600 also includes a 630 coupling. Coupling 630 is connected and sealed (eg via elastomeric “o” rings) to piston mandrel 620 at first end 602. Coupling 630 is then screwed and secured with pins to the housing connector 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.
[0174] [00174] 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 torque screw is provided. provided in 636 by connecting coupling 630 to the NACA 634 key. The NACA shaped keys can (a) secure coupling 630 to the inner mandrel 610 via connector housing 614, (b) prevent coupling 630 from rotating around the inner mandrel 610 and ( c) streamline the mud flow along annular ring 612 to reduce friction.
[0175] [00175] Within plug 600, annular crown 625 around inner mandrel 610 is isolated from main hole 605. In addition, annular crown 625 is isolated from an annular crown (not shown) of the surrounding well. The annular crown 625 allows the transfer of gravel mud from the alternative flow channels (such as bypass tubes 218) through the plug 600. Thus, the annular crown 625 becomes the alternative flow channel (s) ( s) for the shutter 600.
[0176] [00176] 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 tubular body connected and supplies the mud to the annular crown 625. The tubular body can be, first end, an adjacent sand sieve, a blank tube, or a zonal isolation device.
[0177] [00177] 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 section of solids at the end of piston mandrel 620 has an inner diameter and an outer diameter. The load shoulder 626 is placed along the outside diameter. The internal diameter has threads and is screwed tightly to the internal mandrel 610. At least one alternative flow channel is formed between the internal and external diameters to connect the flow between the annular space 5612 and the annular ring 625.
[0178] [00178] The load relief 626 provides a load support point. During apparatus operations, a loading collar or harness (not shown) is placed around the loading boss 626 to allow shutter 600 to be harvested and supported with conventional elevators. The load shoulder 626 is then temporarily used to support the weight of the shutter 600 (and any connected completion devices, such as sand sieve joints already 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 housing connector 614, then to the internal mandrel 610 or base pipe 205, which is screwed onto the housing connector 614.
[0179] [00179] 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 relative to piston mandrel 6209. Specifically, piston housing 640 is driven by hydrostatic downhole pressure. The piston housing 640 can be composed of multiple segments, or joints, connected.
[0180] [00180] 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. The key Release 715 penetrates through both piston mandrel 6209 and internal mandrel 610.
[0181] [00181] 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 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 710 has been moved along an inner surface 608 of inner mandrel 610.
[0182] [00182] 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 outside piston mandrel 620. The three tubular bodies representing inner mandrel 610, piston mandrel 620 and piston housing 640 are held together against relative translational or rotational movement by four keys release 715. Only one of the release keys 715 is seen in Figure 7A; however, four separate keys 715 are radially visible in the cross-sectional view of Figure 6E, described below.
[0183] [00183] 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 cam recess 624 of piston mandrel 620. Cam recess 624 is large enough to allow cam 734 to move radially inward. However, such clearance is restricted in Figure 7A by the presence of the release sleeve 710.
[0184] [00184] We observe 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 annular crown 625 does not extend across the cross section or is too small. Instead, the annular crown 625 employs separate channels radially spaced, which preserve the support for the release keys 715, as best seen in Figure 6E. In other words, the large channels composing the annular crown 625 are located away from the material of the internal mandrel 610 that surrounds the keyholes 615.
[0185] [00185] At each keyhole location, a keyhole 615 is machined through the internal mandrel 610. The keyholes 615 are drilled to accommodate the respective release keys 715. If there are four release keys 715, there will be four separated shoulders circumferentially to significantly reduce annular crown 625. The remaining area of annular crown 625 between adjacent shoulders allows flow in the alternate flow channel 625 to deviate from release key 715.
[0186] [00186] The bosses can be machined as part of the inner mandrel 620 body. More specifically, the material composing the inner mandrel 610 can be machined to form the bosses. Alternatively, the shoulders can be machined as a separate short release chuck (not shown), which is then screwed into the internal chuck 610. Alternatively, the shoulders can be a separate spacer attached between the internal chuck 610 and the piston chuck 620 by welding or other means.
[0187] [00187] It is also noted here that in Figure 6A the piston mandrel 620 is shown as an integral body. However, the piston mandrel part 620, where keyholes 615 are located, can be a separate short release enclosure. This separate enclosure is then connected to the main piston mandrel 620.
[0188] [00188] Each release key 715 has an opening 732. Similarly, release sleeve 710 has an opening 722. Opening 732 of release key 725 and opening 722 of release key 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 inside openings 732, 722 by the release sleeve 710. However, in Figure 7B, the shear pin 720 has been sheared and only a small part pin 720 remains visible.
[0189] [00189] An outer edge of the release key 715 has a rough 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 mate with a reciprocated rough surface within the piston housing 640. The rough joining surface (or teeth) for piston housing 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 mandrel 620 or mandrel internal 610. Preferably, the rough joint surface or teeth 646 reside on the internal face of a separate, short external release sleeve, which is then screwed into piston housing 640.
[0190] [00190] Turning now 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, first end, as described in WO 2009 / 071574, entitled “Improved Centraliser”, with an international filing date of 28 November 2003.
[0191] [00191] The obturator 600 further includes a sealing element 655. When the centralizing member 650 is actuated and centralizes the obturator 600 inside the surrounding well, the piston enclosure 640 continues to drive the sealing element 655 as described in WO 2007 / 107773, entitled “Improved Packer”, which has an international filing date of March 22, 2007.
[0192] [00192] In Figure 6A, the centralizing member 650 and the sealing element 655 are in their insertion position. In Figure 6B, the centralizing member 650 and connected sealing element 655 were activated. This means that the piston housing 640 has moved along the piston mandrel 620, causing both the centering member 650 and the sealing element 655 to fit into the surrounding well wall.
[0193] [00193] Another anchoring system as described in WO 2010/084353 can be used to prevent piston housing 640 from receding. This avoids contraction of the cup-like element 655.
[0194] [00194] As noted, the movement of piston enclosure 640 occurs in response to hydrostatic pressure from 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 key 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 way of the release key 715, so that the teeth 736 of the release key 725 are no longer engaged with teeth 646 of piston housing 640. This position is shown in Figure 7B.
[0195] [00195] 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.
[0196] [00196] An upper end 752 of the laying tool 750 is made up of several radial gripper fingers 760. The clamp fingers 760 collapse when subjected to sufficient internal force. In operation, the pincer fingers 760 join a profile 724 formed along the release sleeve 710. The pincer fingers 760 include raised surfaces 762 that join with the profile 724 of the release key 710. In the union, the placement tool 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 move upward along the inner surface 608 of the inner mandrel 610.
[0197] [00197] As noted, the placement tool 750 can be introduced into the well with a wash tube. The placement tool 750 can simply be a profiled part of the wash tube body. Preferably, however, the laying tool 750 is a separate tubular body 755, which 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 for connection to a drill string or other insertion tube. The connection tool 770 extends into 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 flushing tube or other device, or it can connect to the internal threads (not seen) inside the body 755 of the laying tool 750.
[0198] [00198] Returning to Figures 7A and 7B, the displacement of the release sleeve 710 is limited. In this regard, a first or top end 726 of the release sleeve 710 comes into contact with the shoulder 606 along the inner surface 608 of the inner mandrel 610. The length of the release sleeve 710 is quite short to allow the release sleeve release 710 unclog opening 732 of release key 715. When completely moved, release key 715 moves radially inward, pushed by the rough profile of piston housing 760, when hydrostatic pressure is present.
[0199] [00199] 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 detach teeth 646 from piston housing 640 once the release sleeve 710 seals unobstructed. The hydrostatic pressure then acts on piston housing 640 to translate it downwards relative to piston mandrel 620.
[0200] [00200] After the shear pins 720 have been sheared, piston housing 640 is free to slide along the outer surface of piston mandrel 620. To accomplish this, the hydrostatic pressure of annular crown 625 acts on a shoulder 642 of the piston enclosure 640. This is best seen in Figure 6B. The shoulder 642 serves as a pressure support 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 plunger elements 655 engage the surrounding well.
[0201] [00201] The shutter 600 also includes a measuring device. When the piston enclosure 640 travels along the piston mandrel 620, a measurement hole 664 regulates the extent to which the piston enclosure travels along the piston mandrel, thus slowing the movement of the piston enclosure and regulating the speed placement of the shutter 600.
[0202] [00202] To further understand the aspects of the mechanically placed shutter illustrative 600, several additional cross-sectional views are provided. These are seen in Figures 6C, 6D, 6E and 6F.
[0203] [00203] 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 coupling 630 to the NACA 634 wrench.
[0204] [00204] 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 screwed into the internal chuck 610.
[0205] [00205] Figure 6E is a cross-sectional view of the mechanically placed plug 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 seen that alternative flow channel 625 resides between release keys 715.
[0206] [00206] 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 within piston mandrel 620. When fluid moves through fluid holes 628 and pushes boss 642 of piston housing 640 away from holes 628, a gap annular 672 is created and elongated between piston mandrel 620 and piston housing 640.
[0207] [00207] Once the fluid bypass plug 600 is placed, gravel packing operations can begin. Figures 8A to 8N show stages of a gravel packing procedure in one embodiment. The gravel packing procedure uses 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 mechanically placed shutters can be according to the shutter 600 of Figures 6A and 6B.
[0208] [00208] In Figures 8A to 8N, the sand control devices are used with an illustrative gravel packing procedure in a conditioned drilling mud. The conditioned drilling mud can be a non-aqueous fluid (NAF), such as an oil-based fluid laden with solids. Optionally, a water-based fluid filled with solids is also used. This process, which is a two-fluid process, may include techniques similar to the process discussed in International Patent Application No. WO / 2004/079145 and related US Patent No. 7,373,978, each of which is hereby incorporated. by reference. However, it should be noted that this example is for illustrative purposes only, as other suitable processes and fluids can be used.
[0209] [00209] In Figure 8A, a well 80o is shown. Illustrative well 800 is a horizontal open-bore 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 at each production interval 810, 820 are provided.
[0210] [00210] Each of the sand control devices 850 consists of a base tube 854 and a sand sieve surrounding 856. Base tubes 854 have slits or perforations to allow fluid to flow into the base tube 854. The 850 sand control devices also each include alternative flow paths. These can be according to the 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.
[0211] [00211] 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 and 820. More than one shutter unit 300 can be incorporated. The connection between sand control devices 850 and a shutter unit 300 can be in accordance with U.S. Patent No. 7,661,476 discussed above.
[0212] [00212] In addition to the sand control devices 850, a wash tube 840 has been lowered into well 800. Wash tube 840 is introduced into well 800 below a crossover tool or a gravel package service tool ( not shown), which is attached to the end of an 835 drill pipe or other work column. The wash tube 840 is an elongated tubular member, which extends into the sand sieves 850. The wash 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, such as the displacement tool 750 shown in Figure 7C. The displacement tool 750 is positioned under the plug 300.
[0213] [00213] In Figure 8A, a crossover tool 845 is placed at the end of the production pipe 835. The crossover tool 845 is used to direct the injection and circulation of the gravel sludge, as discussed in more detail below.
[0214] [00214] 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 liner tubes 830. Together, the plug 815, the crossover tool 845, the elongated wash tube 840, displacement tool 750 and gravel pack sieves 850 are inserted into the lower end of well 800. Shutter 815 is then placed in production liner tube 830. The crossover tool 845 is then released from the shutter 815 and is free to move as shown in Figure 8B.
[0215] [00215] Returning to Figure 8A, a conditioned NAF (or other drilling mud) 814 is placed inside well 800. Preferably, drilling mud 814 is deposited inside well 800 and supplied to the hole-open part before the drilling column 835 and the fixed sand sieves 850 and the washing tube 840 attached are introduced into the well 800. The drilling mud can be conditioned on the mesh agitators (not shown) before the sand control devices 850 are introduced into well 800 to reduce any potential obstruction from 850 sand control devices.
[0216] [00216] 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 towards the surrounding column of liner tubes 830 The shutter 815 is placed over 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.
[0217] [00217] After the plug 815 is placed as shown in Figure 8C the crossover tool 845 is moved upwards in an inverse position. Circulation pressures can be measured in this position. In most embodiments, a carrier fluid 812 is pumped drill pipe 835 below and placed within an annular crown between drill pipe 835 and surrounding production liner tube 830 above plug 815. The carrier fluid is a fluid gravel carrier, which is the liquid component of the gravel packaging mud (those skilled in the art will recognize that, in some embodiments, a displacement fluid, which is distinct from the carrier fluid, can be used to displace or assist in displacement of the drilling fluid, before the carrier fluid is introduced into the well which then in turn displaces the displacement fluid. The displacement fluid can comprise the carrier fluid sealing elements other fluid composition. realization are also within the scope internal diameter). The displacement fluid or carrier 812 displaces conditioned drilling fluid 814 above plug 815, which again can be an oil-based fluid, such as conditioned NAF. Carrier fluid 812 displaces drilling fluid 814 in the direction indicated by arrows “C”.
[0218] [00218] Then, in Figure 8D, the crossover tool 845 is moved back into a circulation position. This is the position used to circulate gravel packing sludge and is sometimes referred to as the gravel packing position. The previously placed carrier fluid 812 is pumped down the annulus between the drill tube 835 and the production liner tube 830. The carrier fluid 812 is still pumped down the wash tube 840. This pushes the conditioned NAF 814 down the wash tube 840 , out of the sand sieves 856, sweeping the annular ring of open hole between the sand sieves 856 and the surrounding wall 805 of the open-hole part of the well 800, through the crossover tool 845 and into the drill pipe 835 The flow path of carrier fluid 812 is again indicated by the arrows “C”.
[0219] [00219] In Figures 8E to 8G, the production intervals 810, 820 are prepared for packing of gravel.
[0220] [00220] In Figure 8E, once the annular hole-open crown between the sand sieves 856 and the surrounding wall 805 has been swept away with the carrier fluid 812, the crossover tool 845 is moved back to the reverse position. Conditioned carrier fluid 814 is pumped down annular crown between production tubing 835 and production liner tubing 830 to force carrier fluid 812 out of drill tube 835, as shown by arrows "D". These fluids can be removed from the 835 drill pipe.
[0221] [00221] Next, the plugs 304 are placed, as shown in Figure 8F, by pulling the displacement tool, located under the plunger unit 300, on the washing tube 840 and upwards beyond the plunger unit 300. More specifically , the mechanically placed shutters 304 of the shutter unit 300 are placed. Shutters 304 can be, for example, 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.
[0222] [00222] While in the reverse position, as shown in Figure 8G, the carrier fluid with gravel 816 can be placed inside the drill pipe 835 and used to force the carrier fluid 812 over the annular ring formed between the drill pipe 835 and the production liner tube 830 above the plug 815, as shown by the arrows “C”.
[0223] [00223] In Figures 8H to 8J, the crossover tool 845 can be moved into the circulation position to pack the first subsurface gap 810 with gravel.
[0224] [00224] In Figure 8H, the carrier fluid with gravel 816 begins to create a gravel package within the production range 810 above the annular crown plug 300 between the sand sieve 856 and the wall 805 of the open borehole 800. The fluid flows out of the sand sieve 856 and returns through the wash tube 840, as indicated by arrows "D". The carrier fluid 812 in the annular crown of the well is forced into the sieve, through the washing tube 840 and upwards of the annular crown formed between the drill pipe 835 and the production liner tube 830 above the plug 815.
[0225] [00225] In Figure 8I, a first gravel pack 860 begins to form above the plug 300. The gravel pack 860 forms around the sand sieve 856 and towards the plug 815. The carrier fluid 812 is circulated under the plug 300 and to the bottom of the well 800. The carrier fluid 812 without gravel flows over the wash tube 840 as indicated by the arrows “C”.
[0226] [00226] In Figure 8J, the gravel packing process continues to form the gravel pack 860 towards the shutter 815. The sand sieve 856 is now being completely covered by the gravel pack 860 on top of the shutter 300. The fluid carrier 812 continues to be circulated under the plug 300 and to the bottom of the well 800. The carrier fluid 812 without gravel flows over the wash tube 840, as indicated by the arrows “C” again.
[0227] [00227] Once the gravel package 860 is formed in the first gap 810 and the sand sieves above the plug 300 are covered with gravel, the gravel carrier fluid 816 is forced through the bypass pipes (shown at 318 in Figure 3b ). The gravel carrier fluid 816 forms the gravel package 860 in Figures 8K to 8N.
[0228] [00228] In Figure 8K, the carrier fluid with gravel 816 now flows within the production range 820 under the plug 300. The carrier fluid 816 flows through the bypass tubes and plug 300 and then out of the sand sieve 856. O carrier fluid 816 then flows into the annulus between the sand sieve 856 and the wall 805 of the well 800 and returns through the wash tube 840. The flow of the carrier fluid with gravel 816 is indicated by the arrows “D”, while the flow of the carrier fluid inside the washing tube 840 without the gravel is indicated at 812, shown by arrows "C".
[0229] [00229] It is observed here that the mud only flows through the bypass channels along the sections of the shutter. After that, the sludge will go into the alternative flow channels of the next adjacent sieve joint. Alternative flow channels have both transport and packaging tubes distributed together at each end of a sieve joint. The packaging tubes are provided along the sand sieve joints. The packaging tubes represent side nozzles that allow the mud to fill any voids in the annular crown. The transport pipes will carry the mud further downstream.
[0230] [00230] In Figure 8L, the gravel pack 860 is beginning to form below the shutter 300 and around the sand sieve 856. In Figure 8M, the gravel pack continues to develop the gravel pack 860 from the base of the well 800 upward towards plug 300. Sand sieve 856 under plug 300 was covered by gravel pack 860. The surface treatment pressure increases to indicate that the annular space between sand sieves 856 and wall 805 well 800 is fully packed with gravel.
[0231] [00231] Figure 80 shows the drilling column 835 and the washing tube 840 of Figures 8A to 8N having been removed from well 800. The coating tube 830, the base tubes 854 and the sand sieves 856 remain inside the well 800 over the upper production intervals 810 and lower 820. The obturator 300 and the gravel packages 860 remain placed in the open-hole well 800 following the completion of the gravel packing procedure of Figures 8A to 8N. Well 800 is now ready for production operations.
[0232] [00232] 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.
[0233] [00233] 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 113 (seen in Figure 2, but not shown in Figure 9A).
[0234] [00234] Subsurface interval 114 may be a part of a subsurface formation that once produced hydrocarbons in commercially viable quantities, but has now undergone significant water and hydrocarbon gas invasion. Alternatively, the subsurface gap 114 may be a formation that was originally a water or aquitarde zone or is otherwise substantially saturated with aqueous fluid. In either example, the operator decided to stop the flow of formation fluids from the 114 range into well 900A.
[0235] [00235] A sand control device 200 was placed in well 900A. The sand control devices 200 are in accordance with the sand control devices 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 device sand control device 200. The sand control device 200 also includes a mesh sieve, a wire-wrapped sieve or other radial filter media 207. The base tube 205 and the surrounding filter media 207 preferably comprise a series of joints connected end-to-end. The joints are ideally about 5 to 45 feet long.
[0236] [00236] We note here that the sand control device 200 of Figures 9A and 9B can be of various forms. In some embodiments, the sand control device 200 is a sand sieve, as described in U.S. Patent No. 7,464,752.
[0237] [00237] Figure 10A illustrates a MazeFloTM 1000 sieve in one embodiment. The illustrative sieve 1000 uses three concentric ducts to enable the flow of hydrocarbons while filtering the fines of the formation. In the arrangement of Figure 10A, the first conduit is a base tube 1010; the second conduit is a 1020 mesh or wire mesh; and the third conduit is a 1030 outer wire mesh or screen.
[0238] [00238] Each conduit 1010, 1020, 1030 includes both permeable and waterproof sections. The permeable sections contain a filter medium designed to retain particles larger than a predetermined size, while allowing fluids to pass through. For the first conduit 1010, the permeable sections are represented by slits 1012, while the impermeable section is represented by the blank pipe 1014. For the second conduit 1020, the permeable sections are represented by the screen or wire mesh 1022, while the impermeable section is represented by the blank tube 1024. For the third duct 1030, the permeable sections are represented by the wire mesh or mesh 1032, while the impermeable section is represented by the blank tube 1034. The permeable sections 1022, 1032 are preferably a coiled screen. with wire in which the gap between two wires is sufficient to retain most of the formation sand produced inside well 1050. The waterproof sections 1024, 1034 can also be sieves wrapped with wire, however with the pitch of the wires so small to effectively stop the flow of any fluids through them.
[0239] [00239] Cross-sectional views of sand sieve 1000 are provided in Figures 10B, 10C and 10D. Figure 10B is a cross-sectional view taken through line 10B-10B of Figure 10A; Figure 10C is a cross-sectional view taken through line 10C - 10C of Figure 10A; and Figure 10D is a cross-sectional view taken through line 10D - 10D of Figure 10A.
[0240] [00240] It can be seen in the cross-sectional views of Figures 10B, 10C and 10D that a series of small tubes is arranged radially around the sand sieve 1000. These are bypass tubes 1040. The bypass tubes 1040 connect with alternative flow channels for transporting gravel sludge over part of the well undergoing a gravel packing operation. Nozzles 1042 serve as outlets for the gravel sludge in order to bypass any sand bridges (not shown) or annular crown plug from the well.
[0241] [00241] It can also be seen in the cross-sectional views of Figures 10B, 10C and 10D that a series of optional walls 1059 is provided. The walls 1059 are substantially impervious and serve to create 1051, 1053 flow compartments or joints within the 1020, 1030 conduits. In a three-dimensional perspective, the 1051, 1053 flow joints or compartments can be lengthwise limited by permeable, sectional dividers. , partially permeable or partially impermeable 1069, as shown in Figure 10A.
[0242] [00242] Each of the compartments 1051, 1053 (or flow joints) has at least one entrance and at least one exit. Compartments 1051 reside around the second conduit 1020, while compartments 1053 reside around the first conduit 1010. Compartments 1051, 1053 are adapted to accumulate particles to progressively increase resistance to fluid flow through compartments 1051, 1053 in the event permeable section of a conduit is compromised and allows formation particles to invade.
[0243] [00243] In the arrangement of Figure 10A, the main flow medium for hydrocarbons is the first conduit 1010. A central hole 1005 is formed within the first conduit 1010 to transport hydrocarbon fluids to a surface. The central hole 1005 can be considered an additional compartment. In operation, if the outermost duct 1030 (eg filter medium 1032) fails and particulates enter compartments 1051, the waterproof section 1024 and the permeable section 1022, along the second duct 1020, will however prevent infiltration of sand, while still allowing fluids to pass through. Continuous sand invasion increases the concentration of sand in compartments 1051 around the second flue 1020 and subsequently increases the loss of frictional pressure, resulting in fluid / sand flow gradually decreased through permeable sections 1022 of the second flue 1020. Production of fluid is then diverted to other permeable sections 1032, without failure of the filter medium.
[0244] [00244] This same "support system" also works with respect to the first conduit 1010. If a failure occurs in the second conduit 1020, so that the forming particles pass through the second conduit 1020, then the cracks in the permeable section 1012 of the first conduit 1010 will at least partially filter the formation particles.
[0245] [00245] The number of compartments 1053, 1051 along the respective circumferences of the second 1020 and third 1030 conduits may depend on the size of the borehole for well 1000 and the type of permeable medium used. Fewer compartments would enable a larger compartment size and result in fewer redundant flow paths if sand infiltrates an outer 1051 compartment. A larger number of 1053, 1051 compartments would decrease compartment sizes, increase frictional pressure losses and reduce productivity from the well. The operator can choose to adjust the relative sizes of compartments 1053, 1051.
[0246] [00246] As shown in Figure 10A, preferably at least one impermeable and permeable section of the flow joints are adjacent. Most preferably, at any cross-sectional location of the MazeFloTM sieve, at least one wall of the flow joint must be impermeable. Therefore, in this preferred embodiment there is at least one flow joint that is impermeable adjacent to at least one flow joint that is permeable at any cross-sectional location of the MazeFloTM screen. This preferred embodiment is illustrated in Figures 10B, 10C and 10D, whereby at any given cross-sectional location there is at least one wall that is impermeable and at least one wall that is permeable.
[0247] [00247] Additional details concerning sand sieve 1000 are provided in U.S. Patent No. 7,464,752 cited above. Figures 4a to 4D and Figures 5A and 5D and accompanying descriptive text, found in columns 7 to 9, are incorporated here by reference.
[0248] [00248] As an alternative to the MazeFloTM 1000 sand sieve of Figures 10A to 10D, a separate sand sieve design can be employed that uses inflow control devices, or “ICD’s”. ICD’s are sometimes used with sand control devices to regulate the flow of different downhole production intervals. Examples of known ICD’s include Reslink’s RESFLOWTM, Baker Hughes ’EQUALIZERTM and Weatherford’s FLOREGTM. These devices are typically used in long, horizontal, open-hole completions to balance the inflow into the completion across production intervals or zones. The balanced inflow increases the control of the reservoir and reduces the risk of water or premature gas erupting from a reservoir layer of high permeability or from the waste of a well. In addition, more hydrocarbons can be captured from the toe of a horizontally completed well through the application of inflow control technology.
[0249] [00249] Because gravel packaging operations generally involve passing large amounts of fluid, such as carrier fluid, through a sand sieve, gravel packaging with typical ICD's is not feasible because ICD's represent a substantial restriction of fluid flow into the carrier fluid. In this regard, gravel sludge and production fluids use the same flow paths. The localized and reduced influx of carrier fluid due to ICD’s can cause premature bridging, loose packages, empty filling elements, increased pressure requirements during pumping of gravel packages. U.S. Patent No. 7,198,760 describes three different methods for employing inflow control technology with a gravel packing operation.
[0250] [00250] Figures 11A to 11G show a sand control device 1100, which can be used as part of a well completion system having alternative flow channels. The sand control device 1100 is designed to be attached to a crossover tool (not shown) and to provide one or more flow paths 1114 for a carrier fluid through a sand sieve 1104 and into a base tube 1102 during gravel packaging operations. The gravel packet carrier or fluid may include XC gel (xanthomonas campestris or xanthan gum), viscoelastic fluids having non-Newtorian rheological properties, a fluid viscosified with hydroxyethylcellulose polymer (HEC), a fluid viscosified with refined xanthan polymer (p eg Kelco's XANVIS, a viscosified fluid with viscoelastic surfactant filling elements a fluid having a favorable rheology and sand-carrying capacity for packing a well's gravel.
[0251] [00251] Sand sieve 1104 uses an inflow control device as described in publication Ό92. The inflow control device is a choke 1108 at one end of the sieve 1100. An expandable plug 1112 is provided at the other end of the sieve 1100 to contain production fluids after packing gravel and during production.
[0252] [00252] Figure 11A provides a side view of the illustrative sand control device 1100. Sand control device 1100 includes a tubular member or base tube 1102. Base tube 1102 includes openings 1110 for receiving carrier fluid during a gravel packaging operation and to receive production fluids during later production. The base tube 1102 is surrounded by a sand sieve 1104 having ribs 1105. The sand sieve 1104 includes a permeable section, such as a sieve or filter medium wrapped with wire and a non-permeable section, such as a section of blank tube. The ribs 1105, which are not shown in Figure 11A for simplicity, but are seen in Figure 11C, are used to keep the sand sieve 1104 at a specific distance from the base tube 1102. The space between the base tube 1102 and the sand sieve 1104 forms an annular chamber that is accessible by fluids external to the sand control device 1100 via the permeable section.
[0253] [00253] The sand control device 1100 has a sealing element 1112. Sealing element 1112 is configured to provide one or more flow paths for the openings 1110 filling elements in the inflow control device 1108 during gravel packing operations , and to block the flow path to openings 1110 before or during production operations. As such, the 1100 sand control device can be used to increase operations within a well.
[0254] [00254] In Figure 11A, the sand control device 1100 includes several components used to control the flow of fluids and solids into a well. For example, the sand control device 1100 includes a main body section 1120, an inflow control section 112, a first connection section 1124, a perforated section 1126 and a second connection section 1128, which can be made from steel, metal alloys or other suitable materials. The main body section 1120 can be a part of the base tube 1102 surrounded by a part of the sand sieve 1104. The main body section 1120 can be configured to have a specific length, such as between 10 and 50 feet, and have specific internal and external diameters. The inflow control section 1122 and the perforated section 1126 can be other parts of the same base tube 1102 surrounded by other parts of the sand sieve 1104. The inflow control section 1122 and the perforated section 1126 can be configured to be between 0.5 feet and 4 feet long.
[0255] [00255] The first 1124 and second 1128 connection sections can be used to couple the sand control device 1100 to other sand control devices or tubing, and can be the location of the chamber formed by the base tube 1102 and the sieve of sand 1104 ends. The first 1124 and second 1128 connection sections can be configured to have a specific length, such as 2 inches to 4 feet or other suitable distance, having specific internal and external diameters.
[0256] [00256] In some embodiments, coupling mechanisms can be used within the first 1124 and second 1128 connection sections to form secure and sealed connections. For example, a first connection 1130 may be positioned within the first connection section 1124 and a second connection 1132 may be positioned within the second connection section 1128. These connections 1130 and 1132 may include various methods for forming connections with other devices. For example, the first connection 1130 may have internal threads and the second connection 1132 may have external threads, which form a seal with other sand control devices or another pipe segment. It should also be noted that, in other embodiments, the coupling mechanism for the sand control device 1100 may include connection mechanisms as described in US Patent No. 6,464,261 and US Patent No. 7,661,476, for example .
[0257] [00257] As noted, the sand control device 1100 also includes an inflow control device 1108. The inflow control device 1108 may include one or more nozzles, holes, tubes, valves, tortuous paths, shaped objects or others suitable mechanisms known in the art create a pressure drop. The inflow control device 1108 forms loss of pressure (eg, an object, shaped nozzle) or loss of frictional pressure (eg, geometry / helical tubes).
[0258] [00258] The formation of pressure loss, which is based on the shape and alignment of an object in relation to the fluid flow, is caused by the separation of fluid that is flowing through an object. This results in turbulent pockets of different pressures behind the object. Openings 1110 can be used to provide additional flow paths, such as carrier fluids, during gravel packing operations, because inflow control device 1108 can restrict the placement of gravel by preventing the flow of carrier fluid into the tube base 1102 during gravel packing operations. The number of openings 1110 of the base tube 1102 can be selected to provide adequate inflow during the gravel packing operations, to obtain partial or substantially complete gravel packing. That is, the number and size of the openings 1110 in the base tube 1102 can be selected to provide sufficient fluid flow from the well through the sand sieve 1104, which is used to deposit gravel in the well and to form the gravel package (not shown).
[0259] [00259] The sealing or expansion element 1112 surrounds the base tube 1102. The expansion element 1112 constitutes an expandable material, that is, an expandable rubber element or an expandable polymer. The swelling material can expand in the presence of a stimulus, such as water, conditioned drilling fluid, a completion fluid, a production fluid (i.e., hydrocarbons), another chemical, or any combination thereof. As an example, an expandable material can be placed in the sand control device 1100, which expands in the presence of hydrocarbons to form a seal between the walls of the base tube 1102 and the non-permeable section of the sand sieve 1104. Examples expandable materials include Easy Well Solutions' ConstrictorTM and SellFix's E-ZIPTM or P-ZIPTM. Other expandable materials that are sensitive to fluid chemistry can also be used. These include a format memory polymer, such as the Baker Hughes GeoFORMTM.
[0260] [00260] Alternatively, the sealing element 1112 can be activated chemically, mechanically by removing a wash tube and / or via a signal, electric or hydraulic, to isolate the openings 1110 from the fluid flow during some or all of the sealing operations. production.
[0261] [00261] The sand control device 1100 of Figure 11A also includes branch pipes 106. Branch pipes 1106 provide alternate flow paths for gravel sludge. Techniques for packaging gravel from alternative flow channels with appropriate leakage of fluid through sand sieve 1104 have been demonstrated in the field to obtain a complete gravel package.
[0262] [00262] Figure 11B is a cross-sectional view of sand control 1100, taken through line 11B-11B of Figure 11A. Alternative flow channels or bypass tubes 1106 are seen internal to the sieve 1104. ICD 1108 representing small flow openings is also seen.
[0263] [00263] Figure 11C is a cross-sectional view of the sand control device 1100 taken through line 11C-11C of Figure 11A. The ribs 1105 are shown between the bypass tubes 1106.
[0264] [00264] Figure 11D is a cross-sectional view of the sand control device 1100 taken through line 11D-11D of Figure 11A. The sealing element 1112 is seen around the base tube 1102 in a non-actuated state. In this regard, during gravel packing operations, the sealing element 1112 does not block the flow path 1114 and provides an alternative flow path for the carrier fluid, in addition to the inflow control device 1108. Beneficially, using bypass tubes 1106, larger parts of intervals can be packaged without leaking into the formation. Therefore, bypass tubes 1106 provide a mechanism for forming a substantially complete gravel package along sand sieve 1104, which bypasses the sand and / or gravel bridges.
[0265] [00265] Figure 11E is a cross-sectional view of the sand control device 1100, taken through line 11E-11E of Figure 11A. The bypass tubes 1106 are shown around the permeable section of the base tube 1102. The bypass tubes may include packaging tubes and / or transport tubes. The packaging tubes may have one or more valves or nozzles (not shown) that provide a flow path for the gravel pack mud, which includes a carrier fluid and gravel, for the annulus formed between the sand sieve 1104 and the walls of a well (not shown). Valves can prevent fluids from an isolated gap from flowing through at least one bypass tube to another gap. These bypass tubes are known in the art as further described in U.S. Patent Nos. 5,515,915, 5,890,533, 6,220,345 and 6,227,303. One of the openings 1110 is also visible in Figure 11E.
[0266] [00266] Figure 11F is another side view of the sand control device 1100 of Figure 11A. Production operations have started and production fluids are flowing into base tube 1102, as indicated by arrow 1116. It is seen in Figure 11F that the expandable plug 1112 has been activated and blocks the annular flow at one end of the sand screen 1104. Specifically, sealing element 1112 is blocking fluid flow through openings 1110. In this embodiment, sealing element 1112 includes the multiple individual parts positioned between adjacent branch tubes 1106, or a single sealing element with openings for 1100 bypass tubes.
[0267] [00267] In operation, the sand control device 1100 can be operated in a water based slurry, with a swellable hydrocarbon material used for the sealing element 1112. During the operation of the sieve and gravel packing operations, the chamber between the base tube 1102 and the sand sieve 1104 is opened for fluid flow through the inflow control device 1108 and / or openings 1110. However, during production operations, such as post-well test operations , the sealing element 1112, comprising a swellable hydrocarbon material (or, optionally, individual sections of swellable material), expands to close the chamber within the perforated section 1126. As a result, fluid flow is limited to the inflow control 1108, since the sealing element 1112, comprising a swellable hydrocarbon material, insulates the openings 1110. As a result, the sand control device 1100, which can be coupled to a column of production tubes 130 or other tubing, provides a flow path 1116 for formation fluids through sand sieve 1104 and inflow control device 1108 and into the base tube 1102. Thus, the openings 1110 are insulated to limit fluid flow to only inflow control device 1108, which is designed to control fluid flow from a surrounding range (such as range 112 seen in Figure 1).
[0268] [00268] Figure 11G is a cross-sectional view of the sand control device 1100, taken through line 11G-11G of Figure 11F. The expandable plug 1112 is seen to fill an annular region between the base tube 1102 and the surrounding sieve 1104.
[0269] [00269] Additional details concerning the 1100 sand control device are described in Publ. U.S. Patent No. 2009/0008092. Specifically, paragraphs 0054 to 0057 are incorporated here by reference.
[0270] [00270] Other arrangements for an expandable inflow control device are also provided in Publ. U.S. Patent No. 2009/0008092. Paragraph 0058 and accompanying Figures 5a to 5F describe an embodiment for an expandable plug, in which the sealing element and the bypass tubes are configured to contact radially spaced ribs around the base tube. Paragraphs 0059 to 0061 and accompanying Figures 6A to 6G describe an embodiment for an expandable plug in which the bypass tubes are external to the sand sieve, providing an eccentric configuration. These parts of Publ. U.S. Patent No. 2009/0008092 are also incorporated herein by reference.
[0271] [00271] U.S. Patent Publication No. 2009/0008092 describes two other ways of providing ICD's for a gravel package for use in an open hole completion. Such a way involves the use of a through-flow conduit. The conduit runs along and inside the sand sieve. Paragraphs 0072 and accompanying Figures 9A to 9E describe such an embodiment using internal bypass tubes. Paragraphs 0073 and 0074 and accompanying figures 10A to 10C describe such an embodiment employing internal bypass tubes. These parts of U.S. Patent Publication No. 2009/0008092 are also incorporated herein by reference.
[0272] [00272] Another such way involves the use of a glove. The sleeve can slide or rotate to selectively cover all or part of the 1110 openings. In this way, inflow control is provided. Paragraphs 0075 to 0080 and accompanying Figures 11A to 11F describe the use of a glove. These parts of U.S. Patent Publication No. 2009/0008092 are also incorporated herein by reference.
[0273] [00273] Returning now to Figure 9A, well 900A has an upper filling unit 210 ’and a lower filling unit 210”. The upper obturator unit 210 'is arranged close to the interface of the upper interval 112 and the intermediate interval 114, while the lower obturator unit 210 ”is arranged near the interface of the intermediate interval 114 and the lower interval 116. Each obturator unit 210', 210 ”Is preferably according to the shutter unit 300 of Figures 3A and 3B. In this regard, the shutter units 210 ', 210 ”will each have optically mechanically placed shutters 304. Optionally, the shutter units 210', 210” will also each have an intermediate expandable shutter 308. The mechanically placed shutters are shown in Figure 9A at 212 and 214, while the intermediate expandable plug is shown at 216. The mechanically placed shutters 212, 214 can be in accordance with the plug 600 of Figures 6A and 6B.
[0274] [00274] The two shutters 212, 214 are mirror images of each other, except for the release sleeves (eg, the release sleeve 710 and associated shear pin 720). As noted above, the one-sided movement of a displacement tool (such as displacement tool 750) shears the shear pins 720 and moves the release sleeves 710. This allows the locking elements 655 to be activated in sequence, the lower ones first and then the superiors.
[0275] [00275] 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 packing 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.
[0276] [00276] 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 from sand or another rock matrix, which it 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 the forming fluids from the intermediate gap 114.
[0277] [00277] 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 210 ”shutter unit with the upper shutter 912 and the lower 210” shutter unit with the lower shutter 914 allows the operator to successfully isolate a subsurface gap, such as the intermediate gap 114 of a hole completion. Open.
[0278] [00278] 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 900B can again be according to well 100 of Figure 2. Here, the bottom gap 116 of the hole-open completion is shown. The lower range 116 extends essentially to the base 136 of well 900B and is the lowest zone of interest.
[0279] [00279] 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 water or hydrocarbon gas invasion. Alternatively, subsurface gap 116 may be a formation that was originally a water or aquitarde zone or is otherwise substantially saturated with aqueous fluid. In either example, the operator decided to seal the influx of forming fluids from the lower range 116 to well 100.
[0280] [00280] 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 shutter units 210 ’, 210”, only the bottom shutter unit 210 ”is seen. By positioning the plug 920 on the bottom 210 ”filling unit, the plug 920 is able to prevent the flow of well formation fluids above 200 from the lower gap 116.
[0281] [00281] We have observed that, with respect to the arrangement of Figure 9B, the intermediate gap 114 may comprise a shale matrix or other rock, which is substantially impermeable to the flow of fluid. In this situation, the plug 920 does not need to be placed adjacent to the lower filling unit 210 ”; instead, plug 920 can be placed anywhere above the lower gap 116 and along the intermediate gap 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 consists of unproductive shale, the operator may choose to place the blank tube through this region, with channels of alternative flows, that is, transport tubes, along the intermediate interval 114.
[0282] [00282] A method for completing a borehole is also provided here. The method is shown in Figure 12. Figure 12 provides a flow chart showing steps for a 1200 method of completing an open borehole, in various embodiments.
[0283] [00283] Method 1200 first includes providing a shutter. This is shown in Box 1210. The shutter can be according to the shutter 600 of Figures 6A and 6B. Thus, the plug is a mechanically placed plug that is placed against an open borehole to seal the annular crown.
[0284] [00284] Fundamentally, the obturator 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 sliding the movable piston enclosure along the plug (in relation to the internal mandrel) will activate the sealing element to fit with the surrounding well.
[0285] [00285] 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 to fit with the surrounding well.
[0286] [00286] It is preferred that the shutter also has a centralizing system. An example is the centralizer 650 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 centralizing system. In this way, both the centralizers and the sealing element are placed using the same hydrostatic force.
[0287] [00287] Method 1200 also includes connecting the plug to a sand sieve. This is provided in Box 1220. The sand sieve comprises a base tube and a surrounding filter medium. The sand sieve is equipped with alternative flow channels.
[0288] [00288] Preferably, the plug is one of two mechanically placed shutters having cup-like sealing elements. The two shutters form a shutter unit. The filling unit is placed inside a column of sand sieves or empty spaces equipped with alternative flow channels. Preferably, an expandable plug is placed between the two mechanically placed shutters.
[0289] [00289] As an alternative, the shutter is a first zonal insulation tool and is connected to a sand sieve. A second zone isolation tool is used as a support and is a gravel based zone isolation tool. The use of a gravel-based zonal isolation tool is described below with respect to Figures 14A and 14B.
[0290] [00290] Regardless of the arrangement, method 1200 also includes running the plug and the connected sand sieve into a well. This is shown in Box 1230. In addition, method 1200 includes running a placement tool into the well. This is provided in Box 1240. Preferably, the plug and the connected 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 one or is introduced with a wash tube.
[0291] [00291] Method 1200 then includes moving the placement tool through the internal mandrel of the plug. This is shown in Box 1250. 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.
[0292] [00292] The movement of the insertion tool through the internal mandrel causes the insertion tool to move a sleeve along the internal mandrel. In one aspect, shifting the sleeve will shear one or more shear pins. In either respect, displacement of the sleeve releases the piston housing, allowing the piston housing to move or slide along the plug relative to the internal mandrel. As mentioned above, this movement of the piston enclosure allows the sealing element to be actuated against the wall of the surrounding open borehole.
[0293] [00293] Regarding the moving step of Box 1250, method 1200 also includes transmitting the hydrostatic pressure to the orifice. This is seen in Box 1260. Transmitting hydrostatic pressure means that the well has enough energy stored in a fluid column to create a hydrostatic drop, in which the hydrostatic drop acts against a surface or shoulder in the piston enclosure. Hydrostatic pressure includes pressure of the fluids within the well, whether such fluids are completion fluids or reservoir fluids, and can also include pressure contributed at the bottom of a well by a reservoir. Because the shear pins (including retaining screws) have been sheared, the piston enclosure is free to move.
[0294] [00294] Method 1200 also includes injecting a gravel slurry into an annular region formed between the sand sieve and the surrounding formation. This is provided in Box 1270 of Figure 12. In addition, method 1200 includes injecting the gravel sludge through alternative flow channels. this allows the gravel sludge to at least partially circumvent the sealing element, so that the well is packed-with-gravel within the annular region under the plug. This is shown in Box 1280.
[0295] [00295] A separate method is provided here to complete the well. This method is shown in Figure 13 as method 1300. Figure 3 is also a flowchart showing steps in method 1300.
[0296] [00296] Method 1300 first includes providing a zonal isolation device. This is shown in Box 1310. The zone isolation apparatus is preferably according to the components described above with respect 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.
[0297] [00297] Preferably, the obturator unit will have at least two mechanically placed obturators and an intermediate elongated expandable obturator. The alternative flow channels will move through each mechanically placed plug and the intermediate expandable plug element. Preferably, the zonal isolation apparatus will comprise at least two shutter units separated by sand sieve joints.
[0298] [00298] method 1300 also includes running the zonal isolation device into the well. The step of running the zonal isolation device into the well is shown in Box 1320. The zonal isolation device is introduced in a lower part of the well, which is preferably completed as an open-hole.
[0299] [00299] The open bore part of the well can be completed substantially vertically. Alternatively, the open hole portion can be deflected, or even horizontal.
[0300] [00300] Method 1300 also includes positioning the zonal isolation device in the well. This is shown in Figure 13 in Box 1330. Step 1330 of positioning the zonal isolation apparatus is preferably carried out by suspending the zonal isolation apparatus by 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 of at least one obturator unit is positioned above or near the top of a selected subsurface range.
[0301] [00301] In one embodiment, the open-hole well crosses three separate intervals. These include an upper range, from which hydrocarbons are produced, and a lower range, from which hydrocarbons are no longer being produced in economically viable volumes. Such gaps can be formed from sand or another permeable rock matrix. The ranges may also include an intermediate range, from 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 shutter unit near the top of the lower range or anywhere along the non-permeable intermediate range.
[0302] [00302] In one aspect, at least one obturator unit is placed near the top of an intermediate range. Optionally, a second shutter unit is positioned near the base of a selected range, such as the intermediate range. This is shown in Box 1335.
[0303] [00303] Method 1300 then includes placing the sealing elements mechanically placed in each of the at least one sealing unit. This is provided in Box 1340. Mechanically placing the top and bottom sealing elements means that an elastomeric sealing member (or other) fits into the surrounding well wall. The shutter elements isolate an annular region formed between sand screens and the formation of the surrounding subsurface above and below the shutter units.
[0304] [00304] Beneficially, the step of placing the obturator of Box 1340 is provided before the mud 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 elastomer element. This provides a better seal during the gravel packing operation.
[0305] [00305] The step of Box 1340 can be performed using the plug 600 of Figures 6A and 6B. The mechanically placed open-hole shutter 600 enables gravel package completions to obtain the current flexibility of independent sieve applications (SAS), providing future zonal isolation of unwanted fluids, while enjoying the benefits of a gravel package completion. alternating flow channel.
[0306] [00306] Method 1300 for completing a borehole well also includes injecting particulate sludge into the annular region. This is demonstrated in Box 1350. 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 hole-open part of the well is packed with gravel below, or above and below (but not between) the mechanically placed filling elements.
[0307] [00307] For method 1300, the sequence for packaging may vary. For example, if a premature sand bridge is formed during gravel packing, the annular crown above the bridge will continue to be packed with gravel via fluid leakage through the sand sieve, due to 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.
[0308] [00308] 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.
[0309] [00309] 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 under the plug via the bypass tubes (or alternative flow channels) with side holes allowing the mud 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.
[0310] [00310] Method 1300 also includes producing production fluids at intervals along the open-hole part of the well. This is provided in Box 1360. Production takes place over a period of time.
[0311] [00311] In an embodiment of method 1300, 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 Box 1070. Such a plug can be used on or below the lower filling unit, such as the second filling unit of step 1335.
[0312] [00312] In another example, a straddle plug is placed along the base tube along a selected subsurface interval to be sealed. This is shown in Box 1375. Such a striking may involve placing sealing elements adjacent to the upper and lower sealing units (such as sealing units 210 ’, 210 ″ in Figure 2 or Figure 9A) along a mandrel.
[0313] [00313] It is observed that mechanically placed shutters, used in relation to methods 1200 and 1300 above, are complex downhole tools. The tools must be designed not only to withstand the high temperatures and pressures of a downhole environment, but they must also be reliable enough to provide at least a temporary well seal, while a gravel packing procedure is being carried out at elevated fluid speeds. As such, the mechanically placed shutter is an expensive device. This expense is increased when a obturator unit is employed including two mechanically placed obturators plus an intermediate expandable obturator.
[0314] [00314] Because of the cost, in some examples the operator may wish to use a less expensive gravel-based zonal system, instead of a second mechanically placed shutter. Such a system is based on a long blank tube, surrounded by densely packed sand. Such a system is described in Pat. WO No. 2010/120419, entitled “Systems and Methods for Providing Zonal Isolation in Wells”.
[0315] [00315] Figures 14A and 14B show side and cross-sectional views of a gravel packaging unit 1400 to provide supportive zonal insulation. The unit defines a tubular body having an upstream manifold 1402 at a first end and a downstream manifold 1410 at a second end. In between the upstream manifold 1402 and downstream manifold 1410 there is an elongated base tube 1430.
[0316] [00316] In operation, the gravel sludge is pumped to the bottom of the well until it reaches the upstream distribution pipe 1402. The gravel sludge is then distributed through both a 1404 gravel packing line and a transport 1408. The gravel packing line 1404 serves to supply sludge into an annular region between the gravel packing unit 1400 and the surrounding well (not shown), while the transport line 1408 supplies part of the gravel sludge further down the rock bottom. Thus, the gravel packing line 1404 and the transport line 1408 serve as classic bypass tubes.
[0317] [00317] The gravel packaging line 1404 contains numerous pouring holes 1412. When the gravel sludge enters the gravel packaging line, the sludge exits through holes 1412 and fills the annular space, typically at the base (or toe) ) from the well to the top (or heel) of the well. A plug 1414 prevents the gravel sludge from deviating from the holes 1412.
[0318] [00318] Conveying pipe 1408 moves the sludge from the upstream distribution pipe 1402 to the downstream distribution pipe 1410. In this way, any sand bridges along the blank pipe 1430 are diverted in a downstream flow path. . Preferably, the transport conduit 1408 and the adjacent blank tube 1430 run together in 40 standing sections.
[0319] [00319] The gravel packaging unit 1400 also includes a leaking duct 1406. The leaking duct 1406 represents a wire-wrapped sieve or other filtering arrangement. A constraint 1416 between the leaking duct 1406 and the upstream manifold 1402 minimizes the gravel sludge entering the leaking duct 1406 of the upstream manifold 1402. The leaking duct 1406 receives water (or carrier fluid) during gravel packaging operation and fuses the water (or carrier fluid) with the gravel sludge in the downstream manifold 1410. Alternatively, the leaking duct 1406 may be in direct fluid communication with the conveying duct 1408 above the pipe downstream distribution pipe 1410. At the same time, the drain pipe 1406 filters out particles of sand, leaving the gravel package in position around the blank pipe 1430.
[0320] [00320] The 1400 gravel packaging unit is designed to threadably connect to the base tube of a sand sieve section at one end. At the other end, the gravel packaging unit 1400 is connected to a mechanically placed shutter 600. The gravel packaging unit 1400, at least partially, restricts the flow of production fluids between the production zones or geological intervals of a well open-hole. The 1400 unit's gravel-based insulation system may not be a primary insulation tool, but it substantially restricts flow in the event of failure of a 655 cup-type element. Ideally, the 1400 gravel packaging unit is at least 40 feet and, more preferably, at least 80 feet, in order to provide optimum fluid insulation.
[0321] [00321] Additional details regarding the design and operation of gravel-based zonal insulation systems are found in Publ. Pat. WO No. 2010/120419. This order is hereby incorporated by reference in its entirety.
[0322] [00322] 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 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 (12)
[0001]
Method for completing a well (100) in a subsurface formation, said method characterized by the fact that it comprises: providing a obturator unit (210) having a mechanically placed first obturator (212, 600) as a first zone isolation tool and a second zone isolation tool, wherein each of the first and second zone isolation tools comprises an internal hole for receive production fluids, and alternative flow channels, and the first mechanically placed plug (212, 600) comprises: an internal mandrel (610) as the internal hole, the alternative flow channels (625) along the inner mandrel (610), a movable piston enclosure (640) external to the internal mandrel (610), one or more flow holes (628) providing fluid communication between alternative flow channels (625) and a pressure bearing surface (642) of the piston enclosure (640); and an external sealing element (655) in the internal mandrel (610) and in a selectively movable fit with the piston enclosure; connect the shutter unit (210) to a sand sieve (200), the sand sieve (200) comprising a base tube (205), a surrounding filter medium (207) and alternative flow channels (218), in what: the base tube (205) has an internal hole in fluid communication with the internal hole of the first and second zonal insulation tools, and the alternative flow channels (218) of the sand sieve (200) are in fluid communication with the alternative flow channels (625) of the first and second zonal insulation tools; introduce the plugging unit (210) and sand sieve (200) connected into the well; placing the first mechanically placed plug (212, 600) communicating fluid pressure to the piston housing through one or more orifices to drive the sealing element (655) into engagement with the formation of the surrounding subsurface; inject a gravel mud into the well (100); and inject the gravel sludge at least partially through the alternative flow channels (218, 625) to allow the gravel sludge to bypass the sealing element (655), so that the well is packed with gravel within a region annul between the sand sieve (200) and the surrounding formation under the filling unit (210).
[0002]
Method according to claim 1, characterized in that the filter medium (207) of the sand sieve (200) comprises a sieve wrapped with wire, a membrane sieve, an expandable sieve, a sintered metal sieve, a wire mesh sieve, a memory format polymer or a bed of prepackaged solid particles.
[0003]
Method according to claim 1, characterized in that the second zonal insulation tool is a gravel-based zonal insulation tool (1400) comprising: a distribution pipe (1402) upstream, configured to receive the gravel sludge; a gravel packaging conduit (1404) in fluid communication with the upstream distribution tube (1402) and extending longitudinally away from the upstream distribution tube (1402), the gravel packaging conduit (1404) having a plurality of holes (1412) for placing the gravel packaging duct (1404) in fluid communication with an annular crown between the second zonal insulation tool and the surrounding well (100), and having a plug near a lower end of the duct gravel packaging (1404) to isolate the gravel packaging line from a downstream flow path; a transport conduit (1408) in fluid communication with the distribution pipe (1402) upstream and in fluid communication with the downstream flow path, the transport conduit (1408) serving as the alternative flow channels for the second tool zonal isolation; and a leakage duct (1406) comprising permeable medium in order to place the leakage duct (1406) in fluid communication with the annular crown, but filtering out the gravel packaging particles during a gravel packaging procedure, the leakage duct ( 1406) comprising an elongated tubular body in fluid communication with the downstream flow path.
[0004]
Method according to claim 3, characterized in that the gravel-based zonal isolation tool is at least 40 feet long.
[0005]
Method according to claim 1, characterized in that the second zonal isolation tool comprises a second mechanically placed shutter (214, 600), constructed according to the first mechanically placed shutter (212, 600) and being disposed within the shutter unit (210) as substantially a mirror image of the first mechanically placed shutter (212, 600).
[0006]
Method according to claim 1, characterized in that the second zonal insulation tool comprises an expandable plug (216) adjacent to the first mechanically placed plug (612, 600).
[0007]
Method according to claim 1, characterized by the fact that: the second zonal isolation tool comprises a second mechanically placed plug (214, 600), constructed in accordance with the first mechanically placed plug (212, 600); and the obturator unit (210) further comprises an expandable obturator (216) intermediate the first and second mechanically placed obturators (212, 214, 600), the expandable obturator (216) having alternative flow channels, fluidly connected with the flow channels ( 625) alternatives to the first and second mechanically placed shutters (212, 214, 600).
[0008]
Method according to claim 7, characterized in that the second mechanically placed obturator (214, 600) is disposed within the obturator unit (210) as substantially a mirror image of the first mechanically placed obturator (212, 600).
[0009]
Method according to claim 7, characterized in that the step of still injecting the gravel sludge through the alternative flow channels (218, 625) comprises bypassing the filling unit (210) so that the well (100) is packed with gravel above and below the filling unit (210), after the first and second mechanically placed plugs (212, 214, 600) have been placed in the well (100).
[0010]
Method according to claim 1, characterized by the fact that the sand sieve comprises: a) first conduit forming a primary flow path (605) in fluid communication with the internal mandrel (610) of the first mechanically placed plug (212, 600), the first conduit having at least one section that is permeable and at least one section that is waterproof. b) at least one bypass tube (218) along the length of the first conduit, the at least one bypass tube (218) being in fluid communication with one of the alternative flow channels (625) of the first mechanically placed plug (212 , 600), to transport the gravel sludge; c) a second conduit comprising a secondary flow joint, in which the second conduit also has at least one section that is permeable and at least one section that is impermeable, and in which one of at least one permeable sections of the second conduit is in fluid communication with one of at least one permeable sections of the first conduit, thereby providing fluid communication between the first and second conduits; and d) filter medium (207), the filter medium (207) being designed to retain particles larger than a predetermined size, while allowing fluids to pass into the permeable sections of the first and second ducts.
[0011]
Method according to claim 10, characterized by the fact that: the filter means (207) comprises a first filter screen, placed along the permeable sections of the first conduit and a second filter medium placed along the permeable sections of the second conduit; and the first conduit and the second conduit each comprise a tubular body having a cylindrical wall, with the first conduit and the second conduit running substantially parallel to each other within the well (100).
[0012]
Method according to claim 1, characterized by the fact that: the well (100) has a lower end defining an open-hole part; insert the filling unit (210) and the sand sieve (200) into the well (100) along the hole-open part (120); and place the plug into the borehole (120) of the well (100).

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同族专利:

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公开号 | 公开日

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EP2665888A2|2013-11-27|

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WO2012082305A3|2013-10-17|

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CA2819371A1|2012-06-21|

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SG10201510414VA|2016-01-28|

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SG190713A1|2013-07-31|

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CN103688015B|2016-09-07|

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MY166359A|2018-06-25|

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EA026663B1|2017-05-31|

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US9322248B2|2016-04-26|

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EP2665888A4|2017-11-01|

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CA2819371C|2016-11-29|

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BR112013013147A2|2017-10-31|

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EA201390901A1|2013-12-30|

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EP2665888B1|2019-03-13|

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AU2011341563A1|2013-07-04|

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MX342258B|2016-09-22|

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AU2011341563B2|2016-05-12|

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WO2012082305A2|2012-06-21|

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MX2013006264A|2013-07-12|

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CN103688015A|2014-03-26|

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

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

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

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

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2020-07-21| B16A| Patent or certificate of addition of invention granted [chapter 16.1 patent gazette]|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 17/11/2011, OBSERVADAS AS CONDICOES LEGAIS. |

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2021-09-08| B21F| Lapse acc. art. 78, item iv - on non-payment of the annual fees in time|Free format text: REFERENTE A 10A ANUIDADE. |

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2021-12-28| B24J| Lapse because of non-payment of annual fees (definitively: art 78 iv lpi, resolution 113/2013 art. 12)|Free format text: EM VIRTUDE DA EXTINCAO PUBLICADA NA RPI 2644 DE 08-09-2021 E CONSIDERANDO AUSENCIA DE MANIFESTACAO DENTRO DOS PRAZOS LEGAIS, INFORMO QUE CABE SER MANTIDA A EXTINCAO DA PATENTE E SEUS CERTIFICADOS, CONFORME O DISPOSTO NO ARTIGO 12, DA RESOLUCAO 113/2013. |

优先权:

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申请号 | 申请日 | 专利标题

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

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

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US201161549056P| true| 2011-10-19|2011-10-19|

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US61/549,056|2011-10-19|

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PCT/US2011/061225|WO2012082305A2|2010-12-17|2011-11-17|Wellbore apparatus and methods for multi-zone well completion, production and injection|

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