Patent Grant
7891420
This invention relates generally to an apparatus and method for use in wellbores. More particularly, this invention relates to a wellbore apparatus and method suitable for fluid production and gravel packing through redundant sand control in a single wrapping process.
This section is intended to introduce the reader to various aspects of art, which may be associated with exemplary embodiments of the present invention, which are described and/or claimed below. This discussion is believed to be helpful in providing the reader with information to facilitate a better understanding of particular techniques of the present invention. Accordingly, it should be understood that these statements are to be read in this light, and not necessarily as admissions of prior art.
The production of hydrocarbons, such as oil and gas, has been performed for numerous years. To produce these hydrocarbons, a production system may utilize various devices, such as sand screens and other tools, for specific tasks within a well. Typically, these devices are placed into a wellbore completed in either cased-hole or open-hole completion. In cased-hole completions, wellbore casing is placed in the wellbore and perforations are made through the casing into subterranean formations to provide a flow path for formation fluids, such as hydrocarbons, into the wellbore. Alternatively, in open-hole completions, a production string is positioned inside the wellbore without wellbore casing. The formation fluids flow through the annulus between the subsurface formation and the production string to enter the production string.
However, when producing hydrocarbons from subterranean formations, it becomes more challenging because of the location of certain subterranean formations. For example, some subterranean formations are located in ultra-deep water, at depths that extend the reach of drilling operations, in high pressure/temperature reservoirs, in long intervals, at high production rate, and at remote locations. As such, the location of the subterranean formation may present problems that increase the individual well cost dramatically. That is, the cost of accessing the subterranean formation may result in fewer wells being completed for an economical field development. Accordingly, well reliability and longevity become design considerations to avoid undesired production loss and expensive intervention or workovers for these wells.
As an example, when producing formation fluids from subterranean formations located in deep water, it is possible to produce solid material, such as sand, along with the formation fluids because the formations are poorly consolidated or the formations are weakened by downhole stress due to wellbore excavation and formation fluid withdrawal. Sand control devices are usually installed downhole across these formations to retain solid material, but allow fluids to be produced. Loss of sand control may result in sand production at the surface, downhole equipment damage, reduced well productivity and/or loss of the well. Under the increasingly harsh environments, sand control devices are more susceptible to damage due to high stress, erosion, plugging, compaction/subsidence, etc. Such damage may occur to the sand control devices during transportation, installation, completion, injection, production, or stimulation. In fact, damage to the sand control devices is difficult to predict or prevent. As a result, sand control devices are generally utilized with other methods to manage the production of sand from the subterranean formation.
One of the most commonly used methods to control sand is a gravel pack. Gravel packing a well involves placing gravel or other particulate matter around a sand control device that is coupled to the production string. The sand control device may have openings or may be wrapped by a screen. For instance, in an open-hole completion, a gravel pack is typically positioned between the wall of the wellbore and a screen that surrounds a perforated base pipe. Alternatively, in a cased-hole completion, a gravel pack is positioned between a casing string having perforations and a well screen that surrounds a perforated base pipe. Regardless of the completion type, formation fluids flow from the subterranean formation into the production string through the gravel pack and sand control device.
Other sand control methods utilize may include standalone screens and frac packs to address the sand production problem. Recent technology advance in sand control has been focused on monitoring downhole conditions, improving sand retention, increasing flow performance, and reducing erosion potential. For instance, screens may be designed to enhance sand retention efficiency and flow performance. Similarly, the openings in screens may be adjusted to reduce erosion. Also, sensors may be installed in hollow wires or rods in a sand screen to monitor pressure, temperature, density, etc. to provide information about sand control performance.
Currently, sand control equipment includes little, if any, redundancy that addresses problems with failures resulting in flow impairment. In many instances, the ability of a well to produce at or near its design capacity is sustained by only a “single” barrier to the impairment mechanism. That is, a sand screen may be the only device that is utilized to control sand in unconsolidated formations. As a result, any damage to the installed sand screen may result in the production of sand along with the hydrocarbons. If a gravel pack is installed, screen damage may cause both gravel and sand production. Solids production may result in downhole equipment erosion, productivity impairment, sand handling challenges at the surface, and/or partial or complete loss of well productivity. As a result, workovers or sidetracks are eventually required. Thus, the overall system reliability for well completions has great uncertainty.
Accordingly, the need exists for a more reliable well completion apparatus and method to provide redundancy for screens, alternative flow paths inside the screens, and self-mitigating functionality, which includes compartmentalization to address the uncertainty in mechanical damage of sand control screen.
Other related material may be found in at least U.S. Pat. No. 4,945,991; U.S. Pat. No. 5,095,990; U.S. Pat. No. 5,113,935; U.S. Pat. No. 5,293,935; U.S. Pat. No. 5,476,588; U.S. Pat. No. 5,515,915; U.S. Pat. No. 5,642,781; U.S. Pat. No. 5,642,781; U.S. Pat. No. 5,938,925; U.S. Pat. No. 6,125,932; U.S. Pat. No. 6,227,303; U.S. Pat. No. 6,554,064; U.S. Pat. No. 6,684,951; U.S. Pat. No. 6,715,544; U.S. Pat. No. 6,745,843; and U.S. Patent Application Publication No. 2005/0034860.
In one embodiment, an apparatus associated with the production of hydrocarbons is disclosed. The apparatus includes a tubular member having a central opening within an internal portion of the tubular member, wherein the central opening allows hydrocarbons to flow through the tubular member. Also, the tubular member includes openings between the central opening and a region external to the tubular member. In addition to the tubular member, at least two adjacent wire segments are disposed around the tubular member. The at least two adjacent wire segments create at least two flow paths to the central opening. Also, the at least two adjacent wire segments form at least two openings configured to prevent particles greater than a specific size from entering the openings in the tubular member.
In a first alternative embodiment, a sand control device is disclosed. The sand control device includes a plurality of wire segments disposed around the central opening. At least two adjacent wire segments of the plurality of wire segments create at least one circumferential channel between the at least two adjacent wire segments and around the central opening. Further, at least two adjacent wire segments form at least two openings configured to prevent particles greater than a specific size from entering the central opening.
In a second alternative embodiment, a system associated with production of hydrocarbons is disclosed. The system includes a wellbore utilized to produce hydrocarbons from a subsurface reservoir. Also, the system includes a production tubing string disposed within the wellbore. Finally, the system includes at least one sand control device coupled to the production tubing string and disposed within the wellbore. The at least one sand control device includes a plurality of wire segments disposed around a central opening, wherein at least one pair of adjacent wire segments of the plurality of wire segments create a circumferential channel between the at least one pair of adjacent wire segments and the central opening. Further, the at least one pair of adjacent wire segments form at least two redundant openings to prevent particles greater than a specific size from entering the central opening.
In a third alternative embodiment, a method associated with the production of hydrocarbons is described. The method includes providing a sand control device having wire segments disposed around a central opening. At least one pair of adjacent wire segments of the wire segments creates a circumferential channel between the pair of adjacent wire segments and around the central opening. Also, the at least one pair of adjacent wire segments form at least two redundant openings to prevent particles greater than a specific size from entering the central opening. Then, the sand control device is disposed within a wellbore.
In a fourth alternative embodiment, a method of manufacturing a sand control device is described. The method includes forming wire segments. Then, the wire segments are wrapped around a central opening in a single wrap process. At least one pair of adjacent wire segments create a circumferential channel between the at least one pair of adjacent wire segments and around the central opening. Also, the at least one pair of adjacent wire segments form at least two redundant openings configured to prevent particles greater than a specific size from entering the central opening.
The foregoing and other advantages of the present technique may become apparent upon reading the following detailed description and upon reference to the drawings in which:
In the following detailed description, the specific embodiments of the present invention are described in connection with its preferred embodiments. However, to the extent that the following description is specific to a particular embodiment or a particular use of the present techniques, it is intended to be illustrative only and merely provides a concise description of the exemplary embodiments. Accordingly, the invention is not limited to the specific embodiments described below, but rather; the invention includes all alternatives, modifications, and equivalents falling within the true scope of the appended claims.
The present technique includes a sand control device that may be utilized in a completion, production, or injection system to enhance well completion, e.g., gravel pack, and/or enhance production of hydrocarbons from a well and/or enhance the injection of fluids or gases into the well. Under the present technique, which may be referred to as a “Mazewire system,” wire segments have specific geometric configurations to provide redundancy and additional flow paths through the wire segments of a sand control device. In addition to the specific geometric configurations of the wire segments, different types of wire segments may be utilized together to form channels having partitions, compartments, and baffles, which manage the flow of fluids through the wire segments. That is, wire segments may be utilized to provide redundancy, baffling (staggering), and compartmentalization for a sand control device via the wire segments of wire-wrapped screens. Accordingly, wire segments, which may be a continuous wire or individual wires coupled together, may form channels with combinations of various geometries. By wrapping these around axial rods on a tubular member with a central opening, the openings between two adjacent wire segments may provide multiple channels or flow paths in radial, circumferential, axial, helical or mixed directions. As such, the present techniques may be used in well completions with or without a gravel pack for flow control, hydrocarbon production and/or fluid injection.
Further, it should be noted that International Patent Application No. PCT/US04/01599 describes a wellbore apparatus that combines redundant, baffled (staggered), and compartmentalized sand control to self-mitigate screen damage due to erosion, compaction, and other mechanical causes. However, in the present techniques, wire segments having different geometric patterns are used to provide redundancy, baffling (staggering), and compartmentalization for sand control within a sand control device. Accordingly, these wire segments, which may be a continuous wire or individual wire segments, may self-mitigate screen damage due to erosion, compaction, and other mechanical causes. As such, the wire segments may enhance well reliability and longevity under increasingly challenging downhole conditions.
Turning now to the drawings, and referring initially to
The floating production facility 102 is configured to monitor and produce hydrocarbons from the subsurface formation 108. The floating production facility 102 may be a floating vessel capable of managing the production of fluids, such as hydrocarbons, from subsea wells. These fluids may be stored on the floating production facility 102 and/or provided to tankers (not shown). To access the subsurface formation 108, the floating production facility 102 is coupled to a subsea tree 104 and control valve 110 via a control umbilical 112. The control umbilical 112 may include production tubing for providing hydrocarbons from the subsea tree 104 to the floating production facility 102, control tubing for hydraulic or electrical devices, and a control cable for communicating with other devices within the wellbore 114.
To access the subsurface formation 108, the wellbore 114 penetrates the sea floor 106 to a depth that interfaces with the subsurface formation 108. As may be appreciated, the subsurface formation 108 may include various layers of rock that may or may not include hydrocarbons and may be referred to as zones. The subsea tree 104, which is positioned over the wellbore 114 at the sea floor 106, provides an interface between devices within the wellbore 114 and the floating production facility 102. Accordingly, the subsea tree 104 may be coupled to a production tubing string 128 to provide fluid flow paths and a control cable (not shown) to provide communication paths, which may interface with the control umbilical 112 at the subsea tree 104.
Within the wellbore 114, the production system 100 may also include different equipment to provide access to the subsurface formation 108. For instance, a surface casing string 124 may be installed from the sea floor 106 to a location at a specific depth beneath the sea floor 106. Within the surface casing string 124, an intermediate or production casing string 126, which may extend down to a depth near the subsurface formation 108, may be utilized to provide support for walls of the wellbore 114. The surface and production casing strings 124 and 126 may be cemented into a fixed position within the wellbore 114 to further stabilize the wellbore 114. Within the surface and production casing strings 124 and 126, a production tubing string 128 may be utilized to provide a flow path through the wellbore 114 for hydrocarbons and other fluids. Along this flow path, a subsurface safety valve 132 may be utilized to block the flow of fluids from the production tubing string 128 in the event of rupture or break above the subsurface safety valve 132. Further, packers 134 and 136 may be utilized to isolate specific zones within the wellbore annulus from each other.
In addition to the above equipment, other devices or tools, such as sand control devices 138a-138n and a gravel pack 140, may be utilized to manage the flow of fluids and particles into the production tubing string 128. The sand control devices 138a-138n, which may herein be referred to as sand control device(s) 138, may include wire-wrapped screens, membrane screens, expandable screens and/or wire-mesh screens. For exemplary purposes, the sand control devices 138 are herein described as being wire-wrapped screens that include various wire segments. Also, around the sand control devices 138, a gravel pack or natural sand pack 140 may be disposed to provide additional mechanism to manage the flow of fluids and particles into the production tubing string 128. The sand control devices 138 may manage the flow of hydrocarbons from the subsurface formation 108 to the production tubing string 128.
Typically, a wire-wrapped screen includes a continuous wire spirally wrapped on a set of circularly spaced and axially extended rods. The wire is attached to the axial rods by welding at each contact point. The winding process is designed and controlled to attain the desired opening size between two adjacent wires. The wire wrapped screen may be slipped on a perforated tubular member or base pipe for a slip-on wire-wrapped screen or wrapped directly onto the base pipe in a direct wire-wrapped screen, as is known in the art. The wire segments form a screen that prevents particles, such as sand, sand grains or other solid particles greater than a specific size, from entering the production tubing string 128. Accordingly, exemplary wire segments utilized in a sand control device 138 is shown in greater
To provide sand control, a screen of wire segments 208a-208n is disposed around one or more axial rods 206 may be utilized. The axial rods 206, which may include any number of axial rods 206, may be secured to the base pipe 202 via welds or other similar techniques. The axial rods 206 provide support to one or more wire segments 208a-208n, which may be referred to as wire segments 208. These wire segments 208 prevent or restrict the flow of particles, such as sand, into the central opening 205 of the base pipe 202, as discussed below in greater detail. The wire segments 208 may be continuously wrapped and welded on the axial rods 206. The resulting hollow, cylindrical wire-rod embodiment is slipped on the base pipe 202 and secured to the base pipe 202 by welding metal rings at the two opposite ends. The metal rings also seal the open ends between wire segments 208, axial rods 206, and base pipe 202. Alternatively, the wire segments 208 may be direct-wrapped on the axial rods 206, which are disposed along the external face of base pipe 202. The direct-wrap secures wire segments 208 and axial rods 206 to the base pipe 202. The metal rings are welded at two opposite ends to seal the open ends between wire segments 208, axial rods 206, and base pipe 202. Accordingly, these wire segments 208 may be either slip-on or direct wrap wire segments that are attached to the axial rods 206, which are known methods of attaching wire segments in a sand control device. Also, the wire segments 208 and axial rods 206 may be partially or completely coated with an erosion resistance material (e.g., nickel-based thermal spray or metal shields) to further prevent damage.
In addition, alternate path technology may also be utilized with the axial rods 206 and wire segments 208. The alternate path technology may include a shunt tube 210 that is disposed on the outside of wire segments 208, which are described in U.S. Pat. Nos. 4,945,991 and 5,113,935, or between the base pipe 202 and the wire segments 208, which are described in U.S. Pat. Nos. 5,515,915 and 6,227,303. The shunt tube 210 may include one or more nozzles 212 positioned along the length of the shunt tube 210. If the shunt tube 210 is positioned between the base pipe 202 and the wire segments 208 (
To enhance the sand control device, the wire segments 208 may be wrapped around the base pipe 202 in various directions and with varying pitch. For instance, a wire-wrapped screen may include wire segments wrapped around the base pipe 202 at a constant pitch or at varying pitches. The constant pitch may be utilized to prevent certain sized particles from entering the production tubing string 128, while the varied pitch wire segments 208 may be utilized to manage the amount of fluid flow through various portions of the wire segments 208. In addition, the direction of the wire segments may be adjusted to provide channels or flow paths within the wire segments 208, as discussed below in greater detail. This variation in direction may form flow paths that are perpendicular to the fluid flow through the base pipe 202, parallel to the fluid flow through the base pipe 202, or other angular variations relative to the fluid flow through the base pipe 202.
Further, variations in the geometry of the wire segments 208 may form unique openings and channels within the wire segments 208. The openings may be described as designing openings and restrictive openings. Designing openings may be utilized for sand control and well performance purposes to retain sand grains and allow fluid and fines (silts and clays) to pass through the openings. Restrictive openings may be utilized to retain sand grains and restrict the flow of fluids and fines. Depending upon the magnitude of restriction, restrictive openings may allow no flow, minimum flow, and/or diminishing flow due to fines plugging, as noted above. The restriction may be furnished by wrapping the wire segments 208 to have a narrower opening, lengthy opening, tortuous opening, keystone shape opening and/or any combination thereof.
By utilizing various geometric patterns and combinations of design and restrictive openings, the wire segments 208 may be utilized to construct tortuous flow paths or channels through adjacent pairs of wire segments 208. For instance, because restrictive openings are stronger and more erosion resistant than the designing openings, restrictive openings may be arranged to restrict flow along a channel, which may be referred to as a partition. In particular, openings in each channel of the wire segments may be characterized by having at least one restrictive opening and at least one designing opening. Alternatively, any two adjacent openings may include different combinations of design and restrictive openings to stagger or baffle the fluid flowing into the channels. Accordingly, the use of different openings and geometries in the wire segments 208 may provide additional flow paths and redundancy for the sand control device.
As an example, fluids flow from the subsurface formation 108 into the wellbore 114 and through openings formed by the wire segments 208. With the channels formed in the wire segments 208, fluids may flow through the channels formed in the wire segments 208 and/or may travel directly into the central opening 205 through the openings 204 in the base pipe 202. From the central opening 205, fluid flows through to the floating production facility 102 via the production tubing string 128. Typically, in a damaged sand control device, sand may cause sanding-up of the production tubing string 128 and/or the wellbore 114, downhole equipment damage, or massive sand production at the surface.
However, because of the configuration and geometric patterns of the wire segments 208, particles, such as sand, may be retained by the channels, openings, or compartments formed by the wire segments 208. Accordingly, if one pair of wire segments 208 is eroded or damaged, fluid along with sand may pass into one of the channels associated with that pair of the wire segments 208. Within the channel, the momentum of the incoming sand grains is reduced in the channel due to collisions with the walls formed by the wire segments 208. Depending on both magnitude and direction of sand/fluid momentum, sand grains may be captured by restrictive openings, captured by neighboring staggered designing openings, lose kinetic energy when traveling further along the channel, or stopped and entrapped at a partition formed by the wire segments 208. As additional sand grains are accumulated back to the eroded location along the channel, the flow resistance rises and the sand/fluid flow is diverted into another non-eroded portion of the wire segments 208. That is, the flow of fluids at the eroded portion of the wire segments 208 is reduced or shut off, while well production continues through other flow paths or channels within the wire segments 208. As such, the wire segments 208 may self-mitigate damage to the sand control device at various locations without well intervention.
As a specific example,
In the example of
However, under the present techniques, the wire segments of
In this pattern, redundancy and additional flow paths are provided by the wire segments 402-406. As shown along the fluid flow path 412, redundancy is provided by the double stacked keystone pattern, which provides two restrictive openings 408a and 410a or 408b and 410b between each pair of wire segments 402-406. Indeed, the openings 408a, 408b, 410a and 410b in the wire segments 402-406 have inverse keystone geometry that may minimize plugging. The openings 408a, 408b, 410a and 410b allow fluid to pass through, but prevent particles of specific sizes from passing through. Further, if the wire segments 402-406 are disposed with in an angular direction relative to the fluid flow through the base pipe 202, fluid flow paths 414 and 416 may be utilized to provide a tortuous fluid flow path through the wire segments 402-406. As such, two flow paths are provided through the wire segments 402-406 along with the fluid flow path 412 into the central opening 205.
In an alternative embodiment,
In this pattern, redundancy and additional flow paths are again provided by the wire segments 422-426. As shown along the fluid flow path 434, redundancy is provided by the triple stacked keystone pattern, which provides three restrictive openings 428a, 430a and 432a, and 428b, 430b and 432b between each pair of wire segments 422-426. Again, the inverse keystone geometry may minimize plugging of the wire segments 422-426. In addition, if the wire segments 422-426 are disposed with in an angular direction relative to the fluid flow through the base pipe 202, fluid flow paths 436, 437 and 438 may be utilized to provide a tortuous path through the wire segments 422-426. As such, three flow paths 436-438 are provided through the wire segments 422-426 along with the fluid flow path 434 into the central opening 205.
In a second alternative embodiment,
In this pattern, redundancy and additional flow paths are provided by the wire segments 442-446. As shown along the fluid flow path 452, redundancy is provided by the hyperboloidal pattern, which provides two restrictive openings 448a, 448b, 450a and 450b between each pair of wire segments 442-446. Because the keystone pattern is susceptible to plugging, the hyperboloidal pattern provides dual redundant sand control with inverse keystone openings in the injection direction, along the flow path 452. In addition, if the wire segments 442-446 are disposed with in an angular direction relative to the fluid flow through the base pipe 202, a fluid flow path 454 may be utilized to provide a tortuous path through the wire segments 442-446. As such, an additional flow path is provided through the wire segments 442-446 along with the fluid flow path 452 into the central opening 205.
In
In this geometric pattern, redundancy and additional flow paths are provided by the wire segments 462 and 464. As shown along the fluid flow path 472, redundancy is provided by the geometric pattern, which provides a first restrictive opening 468 and a second designing opening 470 between each pair of wire segments 462 and 464. In addition, if the wire segments 462 and 464 are positioned in an angular direction relative to the fluid flow through the base pipe 202, fluid flow path 476 may be utilized to provide an additional flow path through the wire segments 462 and 464. That is a circumferential channel may be formed within the wire segments 462 and 464. As such, additional flow path 476 is provided through the wire segments 462 and 464 along with the fluid flow path 472 into the central opening 205.
To provide specific flow restrictions and tortuous paths through the wire segments 462 and 464, the width of each of the wire segments 462 and 464 may be modified. For instance, upper portion of the wire segment 462 may be configured to have a width x that is wider than a width y for the lower portion. With these widths, the straight opening 468 may be more resistant to erosion from particles, while still providing a fluid flow path. That is, the opening 468 formed between the rectangular portions of the wire segments 462 and 464 is narrower than the opening 470 between the keystone sections of the wire segments 462 and 464. As a specific example, the width x may be from about 0.005 millimeter (mm) to about 1 mm wider than the width y.
Further, the height of each of the wire segments 462 and 464 may also be modified to provide specific flow restrictions and tortuous paths through the pair of wire segments 462 and 464. For instance, the upper portion may be configured to have a height z, the middle portion may be configured to have a height q, and the lower portion may be configured to have a height w. To provide a more restrictive flow path through the wire segments 462 and 464, the height z of the upper portion may be longer than the heights q and w of the lower and middle portions. Alternatively, to provide larger volume flow paths, the heights q and w for the lower and middle portions may be increased to form larger channels between the wire segments 462 and 464.
Beneficially, in each of these embodiments, the wire segments provide redundant sand control along with additional flow paths through the wire segments. Indeed, the openings in the wire segments of
As can be appreciated, the specific geometric patterns of the wire segments may include different variations, which still provide redundant sand control and additional flow paths through the wire segments. These geometric patterns may include different shapes that are designed to enhance operation in a specific direction, such as an injection well or a production well. Alternatively, the geometric patterns may also include shapes for operating in injection and production wells, as noted in
In addition to the specific geometric patterns of the wire segments, different types of wire segments may be utilized together to form partitions, compartments, and baffles that manage the flow of fluids within a wire-wrapped screen. As noted above, under the present techniques, wire segments of different types may also be used to provide redundancy, baffling (staggering), and compartmentalization for sand control with a wire-wrapped screen, such as sand control device 138. Thus, the wire segments 208, which may be a continuous wire or coupled individual wire segments, may be utilized to form channels having various combinations of curved, wavy or flat geometries. Accordingly, the channels formed by the wire segments are discussed in greater detail in
In this embodiment, the wire segments 502-514 include three alternating patterns or shapes along a single wire. In particular, wire segments 502 and 504 have a first pattern, which includes a partial hyperboloidal portion stacked on a rectangular portion. Wire segments 506, 512 and 514 have a second pattern, which includes a rectangular portion, while wire segments 508 and 510 have a third pattern, which includes a rectangular portion, a partial hyperboloidal portion, and a keystone portion stacked on each other. The length of each wire segment shape may be varied, but for this example, each wire segment is at least two winding (wrapping) around the base pipe 202, which does not exceed one thousand feet for any wire segment.
Accordingly, in this configuration, the wire segments 502-514 form a first or outer screen layer formed by openings 520, 524, 528, 532, 536 and 540 and a second or inner screen layer formed by the openings 522, 526, 530, 534 and 538. The outer and inner screen layers provide a fluid flow path 541 to the central opening 205 or provide a fluid flow path 542 along a channel formed by the wire segments 502-514. Along the fluid flow path 542, fluid flows directly into the central opening 205 through a pair of wire segments 502-514. However, along this flow path 542, the different wire segments 502-514 create a helical or circumferential channel that forms a flow maze for fluids. The channel formed by these wire segments 502-514 may be more clearly understood by viewing
In
During well production, fluid passing through one of the openings 520, 524, 528, 532, 536 and 540 in the outer screen layer flows along the channel between the wire segments 502-514 until exiting through one of the openings 522, 526, 530, 534 and 538 in the inner screen layer. However, when an opening in the outer screen layer, such as opening 520, is damaged, fluid and sand pass into the channel and follow the flow path 542. While fluid may enter the central opening 205 through openings 522, 526, 530, 534 and 538 in the inner screen layer, sand may continue along the flow path 542 to be blocked at the partition formed by wire segments 512 and 514. As the sand flows along the flow path 542, sand continues to dehydrate due to fluid loss or lose momentum (kinetic energy) due to the collision with the wire segments that form the channel walls. As a result, sand may accumulate and pack the channel along the flow path 542 to the eroded section of wire segments. That is, sand grains and particles may pack the channel to diminish or shut off fluid flow from the eroded opening in a self-mitigating manner. Thus, sand and fluid in the wellbore may be diverted to other openings in the wire segments that are intact and operating as designed to continue to produce hydrocarbons without interruption.
In this embodiment, the wire segments 602-608 include three alternating geometric patterns in a single wire. In particular, wire segments 602 and 604 have a first pattern, wire segment 606 has a second pattern, and wire segment 608 has a third pattern. Each of these patterns is a unique geometric pattern that is utilized with an adjacent pattern to form an extended restrictive opening 614, 616, 620, or 622. Again, the length of each wire segment may be varied, but for this example, each wire segment 602-608 may be about at least two windings (wrapping) around the base pipe 202.
Accordingly, similar to the discussion above, the wire segments 602-608 form a first or outer screen layer, which is formed by openings 612, 616 and 620, and a second or inner screen layer, which is formed by openings 614, 618 and 622. The outer and inner screen layers provide a fluid flow path 623 to the central opening 205 or provide a fluid flow path 624 along a helical channel formed by the wire segments 602-608. Along the fluid flow path 623, fluid flow directly into the central opening 205 through the wire segments. However, due to the restriction in opening 614, the flow passing opening 612 may preferably follow flow path 624. Along flow path 624, the different wire segments 602-608 create a helical channel that forms a flow maze for fluids. The channel formed by these wire segments 602-608 may be more clearly understood by viewing
In
During well production, fluid passing through one of the openings 612 and 616, but preferably opening 612, in the outer screen layer flows along the helical channel between the wire segments 602-608 until exiting through one of the openings 614, 618 or 622 in the inner screen layer. However, when an opening in the outer screen layer, such as opening 612, is damaged, fluid and sand pass into the channel and follow the flow path 624. While fluid may enter the central opening 205 through openings 614, 618 and 622 in the inner screen layer, sand may continue along the flow path 624 to be blocked at the partition formed by wire segments 606 and 608. As the sand flows along the flow path 624, sand continues to dehydrate due to fluid loss or lose momentum (kinetic energy) due to the collision with the wire segments 602-608 that form the channel walls. As a result, sand may accumulate and pack the channel along the flow path 624 to the eroded section of wire segments 602 and 604. That is, sand grains and particles may pack the channel to diminish or shut off fluid flow from the eroded opening 612 in a self-mitigating manner. Thus, sand and fluid in the wellbore may be diverted to other openings that are intact and operating as designed to continue to produce hydrocarbons without interruption.
Beneficially, various combinations of these wire segments in
It should be noted that other combinations of wire segments may also be utilized. These other combinations may be based on the specific design desired reliability, productivity, production profile, accessibility, and other functional requirements for the well. For instance, the design of the compartments and baffles formed by the wire segments may depend on factors, such as manufacturing, materials, and/or locale of installation. The functional requirements may include, but are not limited to: exclusion of produced solids (sand control); improved mechanical strength or flexibility; exclusion or inclusion of specific fluids (downhole diversion and fluid conformance); delivery of treatment chemicals (for example, scale inhibitors, corrosion inhibitors, etc.); isolation of specific formation types; control of production rate or pressures; and/or measurement of fluid properties. Also, any number of wire segments may be combined to form channels or flow mazes.
Also, the number of compartments or baffles formed by the wire segments may be based on other design considerations. For instance, fewer compartments may enable larger compartment size and result in fewer redundant flow paths through the wire segments. On the other hand, an excessive number of compartments may decrease the compartment size, increase redundant flow paths, and increase manufacturing complexity. Similarly, a variation of compartments may also be utilized to provide specific functionality for certain intervals of a well. For baffles, the wire segments may include walls to completely or partially redirect fluid flow or change the fluid flow velocity. As such, the compartments or baffles may be formed within the wire segments to perform specific functions for the well.
Further, it should be noted that the present techniques may also be utilized for gravel packing. During gravel packing, the flow direction is similar to well production but gravel pack is continuously disposed around the screen. Accordingly, the wire segments may be configured to provide specific functionalities for gravel packing or may be designed to operate as both in gravel packing and well production.
Further, it should be noted that the present techniques may also be utilized for an injection well. During well injection, the flow direction is reversed, but the wire segments may function similar to well production. Accordingly, the wire segments may be configured to provide specific functionalities for an injection well or may be designed to operate as both an injection and production well.
While the present techniques of the invention may be susceptible to various modifications and alternative forms, the exemplary embodiments discussed above have been shown by way of example. However, it should again be understood that the invention is not intended to be limited to the particular embodiments disclosed herein. Indeed, the present techniques of the invention are to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the invention as defined by the following appended claims.
This application is the National Stage of International Application No. PCT/US06/28884, filed 26 Jul. 2006, which claims the benefit of U.S. Provisional Application 60/722,801, filed 30 Sep. 2005.
| Filing Document | Filing Date | Country | Kind | 371c Date |
|---|---|---|---|---|
| PCT/US2006/028884 | 7/26/2006 | WO | 00 | 2/13/2008 |
| Publishing Document | Publishing Date | Country | Kind |
|---|---|---|---|
| WO2007/040737 | 4/12/2007 | WO | A |
| Number | Name | Date | Kind |
|---|---|---|---|
| 1620412 | Tweeddale | Mar 1927 | A |
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