GB2442611A

GB2442611A - Wellbore production equipment with valve and sealing member

Info

Publication number: GB2442611A
Application number: GB0720053A
Authority: GB
Inventors: Robert Joe Coon; Khai Tran
Original assignee: Weatherford Lamb Inc
Current assignee: Weatherford Lamb Inc
Priority date: 2005-04-08
Filing date: 2006-04-07
Publication date: 2008-04-09
Anticipated expiration: 2026-04-07
Also published as: GB0720053D0; GB2442611B

Abstract

Production equipment for use in a wellbore comprises a pump 450 and a valve 400 disposed in the wellbore. The valve comprises a body 410 having a spring or biasing member 460 and a sealing member 470 configured to axially move inside the body against the first spring to provide a path for fluid to flow from an interior region to an exterior region of the body at a first predetermined pressure difference across the sealing member. The spring is disposed in a chamber of the body, and the chamber is in fluid communication with an inlet of a pump, which may be an electric submersible pump (ESP). The valve may comprise a bypass mechanism comprising a sleeve 430, shear pin 435 and lower port 418 for use when the sealing member becomes inoperational.

Description

PRODUCTiON EQUiPMENT FOR WELLBORE AND METHOD FOR CONTROLLING FLUID

FLOW.

Field of the Invention

Various embodiments of the present invention generally relate to producing fonation fluid from a reservoir, and more particularly, to controlling the flow of fluids between the reservoir and the annulus region.

Description of the Related Art

A completion string may be positioned in a well to produce fluids from one or more formation zones. Completion devices niay include casing, tubing, packers, valves, pumps, sand control equipment and other equipment to control the production of hydrocarbons. During production, fluid flows from a reservoir through perforations and casing openings into the wellbore and up a production tubing to the surface. The reservoir may be at a sufficiently high pressure such that natural flow may occur despite the presence ofopposing pressure from the fluid column present in the production tubing. However, over the 1if of a reservoir, pressure declines may he experienced as the reservoir becomes depleted. When the pressure of the reservoir is insufficient for natural flow, artificial lift systems may be used to enhance production. Various artificial lift mechanisms may include pumps, gas lifi mechanisms, and other mechanisms. One type of pump is the electrical submersible pump (ESP).

An ESP normally has a centrifugal pump with a large number of stages of impellers and diflusers. The pump is driven by a downhole motor, which is typically a large three-phase AC motor. A seal section separates the motor from the pump for equalizing internal pressure of lubricant within the motor to that of the well bore. Often, additional components niay be included, such as a gas separator, a sand separator and a pressure and teniperature measuring module. Large ESP assemblies niay exceed 100 feet (30.5 metres) in length.

An ESP is typically installed by securing ii to a string of production tubing and lowering the ESP assembly into the well. The siring of production tubing may be made up of sections of pipe, each being about 30 feel (9.1 metres) in length.

lithe ESP fails, the ESP may need to be removed from the wellbore for repair at the surface. Such repair may lake an extended amount of time, e.g., (lays or weeks. When the ESP is removed from the welibore, sonic action is typically taken to ensure that formation fluid does not continue to flow to the surface. This is typically done, for example, by applying some type oiheavy weight fluid (also commonly referred to as "kill fluid") into the wellbore to "kill" the well, i.e., to prevent fluid flow from the reservoir to the surface during work-over operations. The hydrostatic pressure from the kill fluid is typically greater than the reservoir pressure. However, when the reservoir pressure exceeds the hydrostatic pressure, fluid from the reservoir otien flows to the surface during work-over operations. In some instances, the "kill" fluid might damage the reservoir making it harder to recover the oil later.

Therefore, a need exists in the art for an improved apparatus and system for controlling the flow of fluid between the reservoir and the surtce.

SUMMARY OF TIlE INVENTION

The invention provides production equipment for use in a weilbore, and a method for controlling fluid flow, as set out in the accompanying claims.

BRIEF DESCRIPTION OF THE DRAWINGS

So that the manner in which the above recited Ieatures of the present invention can be understood in detail, a more particular description of the invention, briefly summarized above, may be had by reference to embodiments, some of which are illustrated in the appended drawings. It is to be noted, however, that the appended drawings illustrate only typical embodiments of this invention and are therefore not to be considered limiting of its scope, for the invention may admit to other equally effective embodiments.

Figure 1 illustrates a partial sectional view of a control valve in accordance with one or niore enihodiments of the invention.

Figure 2 illustrates the control valve in accordance with another embodiment of the invention.

Figure 3 illustrates the control valve in accordance with yet another embodiment of the invention.

Figure 4 illustrates a control valve in accordance with still yet another embodiment of the invention.

Figure 5 illustrates a partial section view of a control valve in accordance with one or more embodiments of the invention.

DETAILED DESCRIPTION

Figure 1 illustrates a partial sectional view of a control valve 100 in accordance with one or more embodiments of the invention. The control valve 100 may be disposed on a string of tubulars 130 inside a casing 125 within a wellbore 120. An electrical submersible pump 150 may be disposed above the control valve 100. The electrical submersible punip 150 serves as an artilicial lift mechanism, driving production fluids from the bottom of the wellbore 120 to the surface. The electrical submersible pump ISO may be disposed above the control valve 1 00 by a distance ranging from about 1 5 fiet to about 300 feet. Although embodiments of the invention are described with re1rence to an electrical submersible pump, other embodiments contemplate the use of other types of artificial Jilt mechanism commonly known by persons of ordinary skill in the art.

The control valve 100 includes a neck 140, which is retrievable from the surface by an external fishing tool or other retrieval means commonly by persons ofordinary skill in the art. The control valve 100 further includes a body I 10, which includes a first spring coupled to a sealing member 170, which has a ball portion 175. The sealing member 170 may also be rclrred to as a dart. The first spring 160 is conhigured to position the ball portion 1 75 against a lower seat 190, even in horizontal applications.

The control valve 100 further includes a second spring 180 coupled to an upper seat 185, which is movable against the second spring 180 under certain conditions.

The control valve 100 further includes a first port 11 2 and a second port 114. The first port 112 is configured to allow fluid from an exterior region 155 of the control valve (e.g., an annulus region) to how into the control valve 100, and more specifically, a region inside the body 110 above sealing member 170. The second port 114 is configured to allow fluid (e.g., formation fluid) from an interior region 195 of the control valve 100 to flow to the exterior region 155 under certain conditions. In an initial position, the second port 114 is blocked by the upper scat 185. In an open position, the second port 114 is configured to allow fluid from the interior region 195 to flow through the second port 114 to the exterior region 155. Operations of the above rehrcnccd components are described in detail in the fbllowing paragraphs.

Figure 1 illustrates an embodiment in which the electrical submersible punip ISO is turned off or removed to the surface. As previously mentioned, in the event that the electrical submersible pump 150 is removed from the wellbore 120, kill fluid is ohlen introduced into wellbore 120 to ensure that formation fluid does not continue to flow to the surface. The kill fluid enters the control valve 100 through the first port 112 and exerts hydrostatic pressure against the sealing member 170. Likewise, in the event that the electrical submersible punip 150 is turned off, production fluid or upper completion fluid enters the control valve 100 through the first port 112 and exerts hydrostatic pressure against the sealing member 1 70. In this embodiment, the pressure of the interior region 195 (i.e., below the sealing member 170) is less than the pressure of the exterior region 155 (e.g., hydrostatic pressure from either the kill fluid or the production fluid). As such, the pressure of the exterior region 155 operates to push the ball portion 175 against the lower seat I 90, thereby forming a seal between the ball portion I 75 and the lower seat 190. This seal is configured to prevent fluid (e.g., kill fluid, production fluid or upper completion fluid) from the exterior region 155 to flow into the interior region 195 and to prevent fluid from the interior region 1 95 to flow to the exterior region 155.

Figure 2 illustrates the control valve 100 in accordance with another embodiment of the invention. In this embodiment, the electrical submersible pump I 50 is turned off or removed from the wellbore 120. Thus, hydrostatic pressure from either the kill fluid or the production fluid operates to push the ball portion 175 toward the lower seat 190.

However, in this enibodinient, the pressure of the interior region 195 (e.g., from formation fluid) is greater than the pressure of the exterior region 155 (e.g., from either the kill fluid or the production fluid) but less than the pressure exerted by the second spring 180 against the upper seat 185. As such, the pressure in the interior region 195 operates to push the sealing member 170, compressing the first spring 160, until the ball portion 1 75 is pressed against the upper seal 1 85. thereby forming a seal between the ball portion 175 and the upper seat 185. The second spring 18() may be configured to exert pressure against the upper seal 185 greater than the pressure of the interior region 195, e.g., the reservoir pressure. For example, the second spring 180 may be rated to exert pressure 1.2 times the amount of reservoir pressure. In this manner, the control valve 100 is configured to prevent fluid flow from the interior region 195 to the exterior region I 55 and to prevent fluid flow from the exterior region 155 to the interior region 195, in the event that the electrical subniersible pump 150 is turned ofl'or removed from 1 5 the wellbore 120 and the pressure of the interior region 195 is greater than the pressure of the exterior region 155 but less than the pressure exerted by the second spring 180 against the upper seat 1 85.

Figure 3 illustrates the control valve 100 in accordance with yet another embodiment of the invention. In this embodiment, the electrical submersible pump ISO is turned on, which creates a suction and operates to draw formation fluid to the surlce. This negative pressure created by the electrical submersible pump 150 being turned on reduces the pressure of the exterior region (e.g., hydrostatic pressure from either the kill fluid or the production fluid), thereby allowing the pressure of the interior region 195 (e.g., reservoir pressure) to overcome the pressure of the exterior region 1 55 and the pressure exerted by the second spring 180 against the upper seat 185. As such, the pressure of the interior region 195 causes the sealing member 170 to push against the upper seat I 85, which pushes against the second spring 1 80, until the upper seal 1 85 is removed from blocking the second port 114. When the second port 114 is open, fluid from the interior region 195 niay flow out to the exterior region 155. In this manner, the control valve 100 is configured to allow fluid from the reservoir to Flow through the control valve 100 to the surface only when the electrical submersible pump 150 is turned on.

Figure 4 illustrates a partial sectional view of a control valve 400 in accordance with one or more enibodjments of the invention. Like control valve I 00, control valve 400 may be disposed on a string of lubulars inside a casing 425 within a wellhore 420. An electrical submersible pump 450 may he disposed above the control valve 400. The S control valve 400 includes a body 410, which includes a first spring 460, a second spring 48() and an upper seal 485 that operate in a manner similar to the first spring 160, the second spring I 80 and the upper seal I 85, respectively. As such, other details about the operation of the first spring 460, the second spring 480 and the upper seal 485 may be found with reference to the first spring 160, the second spring 180 and the upper seat 185 in the paragraphs above.

The control valve 400 also includes a first port 412 and a second port 414. The first port 412 is configured to allow fluid from an exterior region 455 surrounding the control valve 400 to flow into the control valve 400, and more specifically, a region 1 5 above sealing member 470. The second port 414 is configured to allow fluid (e.g., formalion fluid) from an interior region 495 of the control valve 400 to flow to the exterior region 455 under certain conditions. First port 412 and second port 414 operate in a manner similar to the first port 112 and the second port 114. Accordingly, other details about the operation of the first port 412 and the second port 414 may be found with reference to the first port 112 and the second port 114 in the paragraphs above.

In addition, the control valve 400 includes a third port 416, which may be configured to allow fluid from the exterior region 455 to flow into the interior region 495. In one embodiment, the third port 416 is used to inject acid or other fluids to stimulate the reservoir. The control valve 400 further includes an injection sleeve 490 coupled to a third spring 440. The injection sleeve 490 is moveable against the third spring 440 under certain conditions. The injection sleeve 490 includes an opening 415 therethrough, which is configured to align with the third port 416 when the ball portion 475 pushes the injection sleeve 490 against the third spring 440. As such, the control valve 400 may be configured such that when the pressure of the exterior region 455 exceeds the pressure exerted by the third spring 440 against the injection sleeve 490, the ball portion 475 pushes the injection sleeve 490 against the third spring 440 to align the opening 415 with the third port 416, thereby allowing the fluid from the exterior region 455 to flow into the interior region 495.

The control valve 400 may further include a mechanism f'or bypassing the control valve 400 in the event that the control valve 400 is inoperational. For instance, lithe sealing member 470 or the ball portion 475 becomes inoperational, formation fluid ironi the reservoir may still be produced to the surface using the bypassing mechanism. In one embodiment, the control valve 400 includes a contingency sleeve 430, which is held by a shear pin 435, and a fourth port 418, which is configured to allow fluid from the exterior region 455 to push the contingency sleeve 430 downward. The control valve 400 may therefore be configured such that when the pressure of the fluid in the exterior region 455 exceeds a shear value of the shear pin 435, the shear pin 435 breaks, thereby allowing the contingency sleeve 430 to drop. In this manner, in the event that the sealing member 470 and/or the ball portion 475 are inoperational, the control valve 400 may be bypassed by injecting fluid with hydrostatic pressure greater than the shear pin 435 into the exterior region 455 to remove the contingency sleeve 430 from blocking the fourth port 418, thereby providing a flow path between the interior region 495 and the exterior region 455. Embodiments of' the invention also contemplate other bypassing mechanisms commonly known by persons of ordinary skill in the art, such as rupturable disks and the like.

In one embodiment, the shear value of the shear pin 435 is set to 1000 psi (6.9 x 106 Pa). In another embodiment, the shear value of the shear pin 435 is below the value required to burst the casing 425.

Figure 5 illustrates a partial section view of' a control valve 500 in accordance with one or more embodiments of' the invention. The control valve 500 may be disposed on a string of tubulars 530 inside a casing 525 within a wellbore 520. An electrical submersible punip 550 may be disposed above the control valve 500. The control valve 500 includes a body 510, which includes a biasing member 560 configured to bias against a sealing member 570. In one embodiment, the biasing member 560 is configured to exert pressure against the sealing member 570 greater than the pressure of' the interior region 595. The control valve 500 further includes a first port 512 for allowing fluid to flow from an exterior region 555 to a region above the sealing member 570. The control valve 500 further includes a second port 514 for providing a flow path from an interior region 595 to the exterior region 555. The interior region 595 is defined as the region below the sealing member 570.

In operation, the sealing member 57() is configured to he held by a stopping niember 580, which may also be refirred to as a no-go, when the pressure of the interior region 595 is less than the pressure of the exterior region 555. However, the sealing member 570 is configured to axially move inside the body 510 against the biasing member 560 to provide a path for fluid to flow from the interior region 595 to the exterior region 555 at a predetermined pressure difThrence across the sealing member 570. In one embodiment, the predetermined pressure difThrence occurs when the pressure of the interior region 595 exceeds the pressure of the exterior region 555 plus the pressure exerted against the sealing member 570 by the biasing member 560. In another embodiment, the predetermined pressure difference occurs when a pump (e.g., an electrical submersible pump) is turned on.

The control valve 500 may also be configured to operate with other features described with reference to the control valve 400. For example, the control valve 500 may include a bypassing mechanism (not shown) configured to allow fluid to flow between the exterior region 555 and the interior region 595 in the event the sealing member 570 becomes inoperational. As another example, the control valve 500 niay also include an injection sleeve (not shown) configured to operate with the scaling member 570 to provide a path for fluid to flow from the exterior region 555 to the interior region 595 when the pressure of the exterior region 555 exceeds the pressure of the interior region 595 plus the pressure exerted against the sealing member 570 by a second biasing member (not shown).

While the foregoing is directed to embodiments of the present invention, other and further embodiments of the invention may be devised without departing from the basic scope thereof and the scope thereof is determined by the claims that follow.

Claims

CLAIMS: 1. Production equipment for use in a wellbore, comprising: a

pump disposed in the wellbore; a valve disposed in the wellbore, the valve comprising: a body having: a first biasing member; and a sealing member configured to axially move inside the body against the first biasing member to provide a path for fluid to flow from U) an interior region of the body to an exterior region of the body at a first predetermined pressure difThrence across the sealing member, wherein: the first biasing member is disposed in a chaniber of the body, and the chamber is in fluid communication with an inlet of a pump.
2. The production equipment of claim I, wherein the first predetermined pressure difference occurs when the pressure of the interior region exceeds the pressure of the exterior region plus the pressure exerted against the sealing member by the first biasing member.
3. The production equipment of claim 1, wherein the interior region of the body is in fluid communication with a reservoir and the exterior region is in fluid communication with the inlet of the punip.
4. The production equipment of claim I, wherein the pump is an electrical submersible pump.
5. The production equipment of claim I, wherein the valve further comprises a bypassing mechanism for allowing fluid to flow between the exterior region and the interior region in the event that the sealing member becomes inoperational.
6. The production equipment of claim 5, wherein the bypassing mechanism comprises: a lower sleeve; a shear pin holding the lower sleeve against the body; and a lower port for providing a flow path between the exterior region and the interior region.
7. The production equipment of claim 6, wherein the lower sleeve is configured to block the lower port in an initial position and is configured to move away from blocking the lower port when the pressure of the exterior region pushing against the lower sleeve is greater than the shear value of the shear pin holding the lower sleeve against the valve.
8. The production equipment of claim 6, wherein the lower sleeve is configured to axially move inside the body in a downward direction to provide a flow path between the exterior region and the interior region when the pressure of the exterior region is greater than the shear value of the shear pin holding the lower sleeve against the valve.
9. The production equipment of claim 1, wherein the body further has a second biasing member; and wherein the sealing member is configured to move axially against the second biasing member to provide a path for fluid to flow from the exterior region to the interior region at a second predetermined pressure ditThrence across the sealing member.
10. The production equipment of claim 9, wherein the second predetermined pressure difThrence occurs when the pressure of the exterior region exceeds the pressure of the interior region plus the pressure exerted against the sealing member by the second biasing member.
II. The production equipment of claim 9, wherein the body further has: an upper sleeve having a first end and a second end substantially opposite the first end, wherein the upper sleeve comprises an opening therethrough; wherein the second biasing member biases against the second end of the upper sleeve; and an upper port for providing a path for fluid to flow from the exterior region to the interior region.
12. The production equipment of claim Ii, wherein the sealing member is configured to move axially against the first end such that the opening is aligned with the upper port at the second predetermined pressure ditThrence across the sealing member.
13. The production equipment of claim I, wherein the interior region is positioned below the sealing member.
14. The production equipment of claim 1, wherein the valve further comprises a stopping member for providing a resting position for the sealing member when the pressure of the exterior region exceeds the pressure of the interior region.
15. The production equipment of claim 1, wherein the first biasing member is disposed above the sealing member and is configured to exert pressure against the sealing member greater than the pressure of the interior region below the sealing member.
16. The production equipment of claim 1, wherein the valve further comprises a fishing neck retrievable from the surface.
17. A method for controlling fluid flow between an interior region and an exterior region of a valve, comprising: disposing the valve inside a welibore, wherein the valve comprises: a body having: a sealing member; and a first biasing member biased against the sealing member in a first direction; and moving the sealing member in a second direction inside the body against the flrst biasing member to provide a path for fluid to flow from an interior region of the body to an exterior region of the body at a first predetermined pressure difference across the sealing member; and turning a pump disposed inside the wellhore on, thereby creating the first predetermined pressure di flerence.
18. The method of claim 17, wherein the first direction is a downward direction.
19. The method of claim 17, wherein the second direction is an upward direction.
20. The method of claim 17, wherein the first predetermined pressure dif'ference occurs when the pressure of the interior region exceeds the pressure of' the exterior region plus the pressure exerted against the sealing member by the first biasing member.
21. The method of' claim 17, further comprising axially moving the seaiing member in the first direction against a second biasing member to provide a path f'or fluid to flow from the exterior region to the interior region at a second predetermined pressure difference across the sealing member.
22. The niethod of' claim 21, wherein the second predetermined pressure difference occurs when the pressure of' the exterior region exceeds the pressure of' the interior region plus the pressure exerted against the sealing member by the second biasing member.
23. The method of'claim 21, wherein axially moving the sealing member in the first direction comprises pushing an upper sleeve against the second biasing member to provide the path for fluid to flow from the exterior region to the interior region at the second predetermined pressure di ft rence across the sealing member.
24. The method of claim 21, further comprising axially moving a lower sleeve disposed inside the body in the first direction to provide a flow path between the exterior region and the interior region when the pressure of' the exterior region is greater than the shear value of'a shear pin holding the lower sleeve against the body.
25. The method of' claim 1 7, wherein valve is disposed between the punip and a reservoir.
26. The method of claim 25, wherein the pump in an electrical submersible pump.
27. The method of claim 17, wherein the interior region is positioned below the S sealing member. 1 0