EP2666957A2 - Gas lift valve with ball-orifice closing mechanism and fully compressible dual edge-welded bellows - Google Patents
Gas lift valve with ball-orifice closing mechanism and fully compressible dual edge-welded bellows Download PDFInfo
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- EP2666957A2 EP2666957A2 EP20130168990 EP13168990A EP2666957A2 EP 2666957 A2 EP2666957 A2 EP 2666957A2 EP 20130168990 EP20130168990 EP 20130168990 EP 13168990 A EP13168990 A EP 13168990A EP 2666957 A2 EP2666957 A2 EP 2666957A2
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- Prior art keywords
- valve
- bellows
- stem
- stem component
- housing
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- 230000009977 dual effect Effects 0.000 title description 2
- 238000007789 sealing Methods 0.000 claims abstract description 37
- 239000012530 fluid Substances 0.000 claims description 49
- 238000000034 method Methods 0.000 claims description 11
- 229920002545 silicone oil Polymers 0.000 claims description 3
- 230000006835 compression Effects 0.000 abstract description 27
- 238000007906 compression Methods 0.000 abstract description 27
- 239000007789 gas Substances 0.000 description 119
- 238000002347 injection Methods 0.000 description 34
- 239000007924 injection Substances 0.000 description 34
- 238000004519 manufacturing process Methods 0.000 description 28
- 238000006073 displacement reaction Methods 0.000 description 13
- 239000000463 material Substances 0.000 description 11
- 238000002955 isolation Methods 0.000 description 6
- 238000013016 damping Methods 0.000 description 5
- 230000000712 assembly Effects 0.000 description 4
- 238000000429 assembly Methods 0.000 description 4
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- 230000003139 buffering effect Effects 0.000 description 4
- UONOETXJSWQNOL-UHFFFAOYSA-N tungsten carbide Chemical compound [W+]#[C-] UONOETXJSWQNOL-UHFFFAOYSA-N 0.000 description 4
- 239000004215 Carbon black (E152) Substances 0.000 description 3
- 238000010586 diagram Methods 0.000 description 3
- 229930195733 hydrocarbon Natural products 0.000 description 3
- 150000002430 hydrocarbons Chemical class 0.000 description 3
- 229910052751 metal Inorganic materials 0.000 description 3
- 239000002184 metal Substances 0.000 description 3
- 230000008901 benefit Effects 0.000 description 2
- 230000008602 contraction Effects 0.000 description 2
- 238000013461 design Methods 0.000 description 2
- 238000005297 material degradation process Methods 0.000 description 2
- 238000005086 pumping Methods 0.000 description 2
- 230000002441 reversible effect Effects 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- 230000007704 transition Effects 0.000 description 2
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 1
- 238000010793 Steam injection (oil industry) Methods 0.000 description 1
- 239000004568 cement Substances 0.000 description 1
- 229910001873 dinitrogen Inorganic materials 0.000 description 1
- 230000005611 electricity Effects 0.000 description 1
- 238000005538 encapsulation Methods 0.000 description 1
- 230000001747 exhibiting effect Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012856 packing Methods 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 230000002035 prolonged effect Effects 0.000 description 1
- 230000004044 response Effects 0.000 description 1
- 230000000630 rising effect Effects 0.000 description 1
- 230000002459 sustained effect Effects 0.000 description 1
- 238000012546 transfer Methods 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
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Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
- E21B43/121—Lifting well fluids
- E21B43/122—Gas lift
- E21B43/123—Gas lift valves
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
- Y10T—TECHNICAL SUBJECTS COVERED BY FORMER US CLASSIFICATION
- Y10T137/00—Fluid handling
- Y10T137/0318—Processes
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
- Y10T—TECHNICAL SUBJECTS COVERED BY FORMER US CLASSIFICATION
- Y10T137/00—Fluid handling
- Y10T137/2931—Diverse fluid containing pressure systems
- Y10T137/2934—Gas lift valves for wells
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Safety Valves (AREA)
- Lift Valve (AREA)
- Details Of Valves (AREA)
Abstract
Description
- This application claims benefit of
U.S. Provisional Patent Application No. 61/650,632, filed May 23, 2012 - Aspects of the present disclosure generally relate to high pressure valves and, more particularly, to valves for use in hydrocarbon wells configured for gas lift operations.
- To obtain hydrocarbon fluids from an earth formation, a wellbore is drilled into the earth to intersect an area of interest within a formation. The wellbore may then be "completed" by inserting casing within the wellbore and setting the casing therein using cement. In the alternative, the wellbore may remain uncased (an "open hole" wellbore), or may be only partially cased. Regardless of the form of the wellbore, production tubing is typically run into the wellbore primarily to convey production fluid (e.g., hydrocarbon fluid, as well as water) from the area of interest within the wellbore to the surface of the wellbore.
- Often, pressure within the wellbore is insufficient to cause the production fluid to rise naturally through the production tubing to the surface of the wellbore. Thus, to force the production fluid from a reservoir to the surface of the wellbore, artificial lift means are sometimes employed. Gas lift and steam injection are examples of artificial lift means for increasing production of oil and gas from a wellbore.
- Gas lift systems are often the preferred artificial lifting systems because operation of gas lift systems involves fewer moving parts than operation of other types of artificial lift systems, such as sucker rod lift systems. Moreover, because no sucker rod is required to operate the gas lift system, gas lift systems are usable in offshore wells having subsurface safety valves that would interfere with a sucker rod.
- Gas lift systems commonly incorporate valves in side pocket mandrels to enable the lifting of production fluid to the surface. Ideally, the gas lift valves allow gas from the tubing annulus to enter the production tubing through the valve, but prevent reverse flow of production fluid from the tubing to the annulus.
- Certain aspects of the present disclosure provide a gas lift valve incorporating two edge-welded bellows assemblies. The gas lift valve incorporates features enabling enhanced compression of one of the bellows, beyond an initial closure point of the valve.
- Certain aspects of the present disclosure provide a valve for downhole gas lift operations. The valve generally includes a housing having an inlet and an outlet for fluid flow; a seat disposed in the housing for controlling the fluid flow from the inlet to the outlet; a stem configured to move in the housing, wherein a sealing element associated with the stem is configured to mate with an orifice in the seat to prevent the fluid flow from the inlet to the outlet, thereby closing the valve; first bellows coupled to the housing and to the stem; and second bellows coupled to the housing and to a movable piston of a variable volume dome in the housing, wherein the second bellows are fully compressed when the valve is closed.
- Certain aspects of the present disclosure provide a method for performing downhole gas lift operations. The method generally includes providing a valve and opening the valve. The valve generally includes a housing having an inlet and an outlet for fluid flow; a seat disposed in the housing for controlling the fluid flow from the inlet to the outlet; a stem configured to move in the housing, wherein a sealing element associated with the stem is configured to mate with an orifice in the seat to prevent the fluid flow from the inlet to the outlet, thereby closing the valve; first bellows coupled to the housing and to the stem; and second bellows coupled to the housing and to a movable piston of a variable volume dome in the housing, wherein the second bellows are fully compressed when the valve is closed. Opening the valve generally involves injecting gas downhole, wherein an injected gas pressure is greater than a dome gas pressure in the variable volume dome, such that the stem moves away from the seat to allow the fluid flow between the inlet and the outlet via the orifice.
- Certain aspects of the present disclosure provide a system for downhole gas lift operations. The system generally includes casing disposed in a wellbore; production tubing disposed in the casing; and at least one valve. The at least one valve generally includes a housing having an inlet and an outlet for fluid flow, wherein the fluid flow enters the inlet from an annulus between the casing and the production tubing and exits the outlet into the production tubing; a seat disposed in the housing for controlling the fluid flow from the inlet to the outlet; a stem configured to move in the housing, wherein a sealing element associated with the stem is configured to mate with an orifice in the seat to prevent the fluid flow from the inlet to the outlet, thereby closing the valve; first bellows coupled to the housing and to the stem; and second bellows coupled to the housing and to a movable piston of a variable volume dome in the housing, wherein the second bellows are fully compressed when the valve is closed.
- According to certain aspects, the stem includes a first stem component and a second stem component mechanically coupled to the first stem component. The first and second stem components may be configured to move in relation to one another. For certain aspects, the first stem component is mechanically stopped by the seat when closing the valve, and the second stem component continues to travel until the second bellows are fully compressed (providing a second mechanical stop). For certain aspects, the first stem component has a slot, and the second stem component has a pin configured to travel within the slot as the first or the second stem component moves in relation to the other stem component. The first and second stem components may be mechanically coupled by a spring. For certain aspects, the spring may alternatively occupy a space in a variable volume valve chamber between the first and second stem components, without being coupled to one or both stem component/s.
- According to certain aspects, the first stem component is mechanically stopped by the seat when the sealing element mates with the orifice. The second stem component may be configured to continue moving in relation to the first stem component until the second bellows are fully compressed.
- According to certain aspects, a portion of the second stem component is hollow and is filled with a non-compressible fluid for protecting at least one of the first or second bellows from damage when the bellows are exposed to gas pressures. For certain aspects, the non-compressible fluid is silicone oil. For certain aspects, the non-compressible fluid is configured to prevent chatter in at least one of the first or second bellows as the non-compressible fluid is transferred between the first and second bellows via the hollow portion of the second stem component.
- According to certain aspects, the sealing element is a ball disposed at a tip of the stem. The ball may be composed of tungsten carbide (WC), for example, or any other suitable material (e.g., a very hard and wear-resistant material). For certain aspects, at least one of the first and second bellows are edge-welded bellows. For certain aspects, the first bellows are fully compressed when the valve is open. When the bellows are fully compressed, the bellows cannot be damaged by external pressures (up to very high values), since the bellows cannot travel any further to compression after being fully compressed. Thus, the valve may be configured to operate in external pressures of up to 10,000 psi or higher.
- A valve for performing gas lift operations may be provided that incorporates two edge-welded bellows and a ball-orifice closing mechanism. The gas lift valve may incorporate features enabling enhanced compression of one of the bellows, beyond an initial closure point of the valve. For example, a stem with the sealing ball may be divided into two components. One of the stem components may be configured to continue moving in relation to the other stem component with the ball, which is fixed in position when the ball seals the orifice and initially closes the valve. This continued movement may allow one of the bellows to be fully compressed in the ultimately closed valve position, thereby protecting the bellows from high pressures and potential failure that could occur to bellows in a partially compressed state.
- The invention includes one or more corresponding aspects, embodiments or features in isolation or in various combinations whether or not specifically stated (including claimed) in that combination or in isolation. For example, it will readily be appreciated that features recited as optional with respect to the first aspect may be additionally applicable with respect to the other aspects without the need to explicitly and unnecessarily list those various combinations and permutations here (e.g. the valve of one aspect may comprise features of any other aspect). Optional features as recited in respect of a method may be additionally applicable to an apparatus; and vice versa. For example, a valve may be configured to perform a step of a related method.
- In addition, corresponding means for performing one or more of the discussed functions are also within the present disclosure.
- It will be appreciated that one or more embodiments/aspects may be useful in connecting and/or disconnecting electricity, such as bus-bars.
- The above summary is intended to be merely exemplary and non-limiting.
- So that the manner in which the above recited features of the present disclosure can be understood in detail, a more particular description of the various aspects, 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 disclosure and are therefore not to be considered limiting of its scope, for the disclosure may admit to other equally effective embodiments.
-
FIG. 1 is a section view of a gas injection wellbore. -
FIG. 2 is a section view of a side pocket mandrel incorporating a gas lift valve in accordance with aspects of the present disclosure. -
FIGs. 3A ,3B , and3C are vertical cross-sectional illustrations of an example gas lift valve in different operating states, in accordance with aspects of the present disclosure. -
FIG. 4 is a flow diagram of example operations for performing downhole gas lift, in accordance with aspects of the present disclosure. - A typical
gas lift completion 10 illustrated inFIG. 1 may include awellhead 12 atop acasing 14 that passes through a formation.Production tubing 20 positioned in thecasing 14 may have a number ofside pocket mandrels 30 and aproduction packer 22. To conduct a gas lift operation, operators conventionally installgas lift valves 40 in the side pocket mandrels 30. - With the
valves 40 installed, compressed gas G from thewellhead 12 may be injected into theannulus 16 between theproduction tubing 20 and thecasing 14. In theside pocket mandrels 30, thegas lift valves 40 then act as one-way valves by opening in the presence of high-pressure injection gas, thereby allowing the gas to flow from theannulus 16 to thetubing 20. When pressure is reduced as a result of discontinued pumping of gas at the surface, the valve closes to prevent reverse production fluid flow from thetubing 20 to theannulus 16. - Downhole, the
production packer 22 forces upwards travel through theproduction tubing 20 of produced fluid P enteringcasing perforations 15 from the formation. Additionally, thepacker 22 keeps the gas flow in theannulus 16 from entering thetubing 20. - The injected gas G passes down the
annulus 16 until it reaches the side pocket mandrels 30. Entering the mandrel'sinlet ports 35, the gas G first passes through thegas lift valve 40 before it can pass into theproduction tubing 20. Once in thetubing 20, the gas G can then rise to the surface, lifting production fluid in the production tubing in the process. - Aspects of the present disclosure provide design features for a gas lift valve that may help to prevent material damage of valve bellows exposed to high pressure.
- Certain gas lift valve designs incorporate a ball sealing element that, in a closed position, covers and seals an orifice in a seat and conduit (designed to channel gas flow from the
annulus 16 and valve interior to theproduction tubing 20 when the valve is open). The ball sealing element may be coupled to a stem or other similarly configured valve component configured to variably move based on the net upwards or downwards expansion force of pressurized gas in opposing valve chambers or compartments. The ball sealing element may be composed of tungsten carbide (WC) or any other suitable material that is very hard and wear-resistant. - In the absence of injection gas, these movable components travel in a closing direction due to dominance of a biasing pressure. In the presence of injection gas (at a sufficient pressure to overcome the biasing force), these movable components shift in an opening direction.
- Commonly, these gas lift valves employ bellows assemblies which are compressed and expanded with the downwards and upwards movement of valve components. However, in many cases, the valve configuration results in the bellows being subjected to high pressures. At the same time, the valve configuration may result in the bellows not being fully volumetrically compressed due to physical limitations imposed by closure of the valve.
- When bellows are subjected to high pressure, their material durability may be significantly reduced if the bellows are prevented from being fully compressed. As used herein, the term "fully compressed" generally refers to the individual washers of the bellows being flattened to form a stack of washers that effectively forms a solid tube of metal. In a partially compressed state (where the individual washers are not flattened) the bellows may be subject to collapse in the presence of very high pressures, possibly leading to failure of the valve.
- Prolonged operation of bellows under high pressure in an intermediately compressed state may result in material degradation or failure of the bellows and a corresponding loss of valve functionality. Aspects of the present disclosure, however, may take advantage of the feature that bellows may exhibit impressive durability when maintained in a fully compressed state under high pressure.
- Aspects of the present disclosure provide a bellows arrangement that allows the bellows to be maintained in a fully compressed state when the gas lift valve is closed.
- As will be described in greater detail below, the gas lift valve may involve a ball sealing element, upper and lower stem components, upper and lower bellows, and a spring element configured so to avoid physical restrictions that might otherwise impede full compression of the upper bellows upon valve closure. The upper bellows may be maintained in a state of heightened compression for so long as the valve continues to be closed, thereby making the upper bellows less vulnerable to material failure.
-
FIG. 2 is a diagram showing an example disposition of agas lift valve 300 of the present disclosure in aside pocket mandrel 30. As depicted, an entrance port 302 (an inlet) of the gas lift valve may be placed adjacent amandrel port 35 such that pressurized injection gas may enter the valve from theannulus 16, and flow through the valve into the production tubing. Packing seals 202, 204 may be used between thevalve 300 and the walls of theside pocket mandrel 30 on either side of theentrance port 302 and themandrel port 35. Also depicted inFIG. 2 are upper bellows 310 (shown in an expanded state), lower bellows 304 (shown in a compressed state), anupper stem component 308, alower stem component 318, anexit conduit 324, and an exit port 325 (an outlet). -
FIGs. 3A ,3B , and3C illustrate thegas lift valve 40 in different operating states.FIG. 3A shows the valve when in an ultimately closed state, with a top bellows fully compressed.FIG. 3B shows the valve in an open state.FIG. 3C shows the valve in an initially closed state, with the valve sealed, but the upper bellows only partially compressed. - For clarity and explanatory purposes only, and in accordance with the depiction in
FIGs. 3A ,3B , and3C , all further discussion of gas lift valves in the present disclosure will assume that the gas lift valve is mounted vertically, that opening the valve entails primarily upwards movements of movable valve components, and that closing the valve entails primarily downwards movement of these valve components. However, this convention is not meant to restrict the scope of this disclosure, and the embodiments described herein admit of any orientation, dimensions, and direction of valve operations, from slightly off-vertical to fully horizontal. - The
gas lift valve 300 may be configured to allow only one-way flow of pressurized injection gas from theannulus 16, through the valve and into theproduction tubing 20. The valve may be configured such that injection gas flowing in the one-way direction may freely enter the gas lift valve from theannulus 16 through theentrance port 302. - Once within the valve, the injection gas may be channeled first into a multicompartment variable
volume valve chamber 326. If the gas pressure is sufficiently high so that the valve is opened, as shown inFIG. 3B , the gas may then flow freely through theorifice 322 and into theexit conduit 324. - The
orifice 322 may form the valve end of theexit conduit 324, and the seating element 323 (or seat) having the orifice may be composed of tungsten carbide or any other suitable material (e.g., a very hard and wear-resistant material). The injection gas may then be channeled out of the valve and into theproduction tubing 20 through the exit conduit and theexit port 325 in the nose of the valve. - The
gas lift valve 300 may be configured to enable pressurized flow in the one-way direction (as shown inFIG. 3B ) and to restrict backflow through the operation of aball sealing element 320 which may be rigidly disposed at the lowest point (e.g., the tip) of the lower stem component 318 (when in the initially closed state as shown inFIG. 3C or in the ultimately closed state as shown inFIG. 3A ). - The sliding stem may be divided into an
upper stem component 308 and alower stem component 318 for reasons which are described in detail below. For some embodiments, the lower stem component may be linked to the upper stem component via aspring element 316. For other embodiments, thespring element 316 may alternatively occupy space in the variablevolume valve chamber 326 between the upper and lower stem components, without being coupled to either stem component. - For some embodiments, the valve may be configured with a variably engaged slot-
pin mechanism 358 comprising aslot 356 in thelower stem component 318 and apin 354 or other protuberance associated with theupper stem component 308 and disposed in the slot. Themechanism 358 may comprise more than one slot-pin combination, such as another slot-pin combination opposite theslot 356 depicted inFIGs. 3A-3C or two more slot-pin combinations spaced 120° apart. The upper andlower stem components spring element 316 and the slot-pin mechanism 358 when it is engaged. The slot-pin mechanism may further serve to prevent rotational or horizontal displacement of theupper stem component 308 relative to thelower stem component 318, and vice versa. - As shown in
FIG. 3A , thegas lift valve 300 may close to restrict backflow through downwards displacement of theupper stem component 308, thelower stem component 318, and theball sealing element 320. This downwards displacement of theball sealing element 320 may result in the ball sealing element abutting the sealingelement 323 and partially entering theorifice 322 from above, thereby sealing the orifice and closing the valve. The contact between theball sealing element 320 and theseating element 323 may also immediately impede further downwards movement of thelower stem component 318, thereby imposing a "mechanical stop" on the lower stem component. Thereafter, and with thevalve 300 remaining sealed, theupper stem component 308 may, for a time, continue to be displaced downwards against thespring element 316 to facilitate increased compression of the upper bellows 310. - The
gas lift valve 300 may include a sealed,variable volume dome 314 containing a pressurized gas (e.g., charged nitrogen gas) to provide a biasing force to close the valve in the absence of injection gas. Thevariable volume dome 314 may be configured such that the pressurized gas constantly imparts a biasing force on theupper stem component 308 which urges the upper stem component in a downwards, sealing direction. As will be explained in greater detail below, thegas lift valve 300 may be configured such that theupper stem component 308 may distribute the biasing force to thelower stem component 318 through the engaged slot-pin mechanism 358, through thespring element 316, or a combination of the slot-pin mechanism and spring element. - For some embodiments, with the valve open and the magnitude of counteracting gas pressure forces in the valve sufficiently small, the urging of the biasing force may be sufficient to cause valve closure. Valve closure may occur in two distinct, but consecutive stages of movement. The first stage may primarily involve the upper and
lower stem components ball sealing element 320 contacts theseating element 323 and seals theorifice 322, as shown inFIG. 3C . The second stage may involve thelower stem component 318 and theball sealing element 320 being held fast to remain in position, with theball sealing element 320 being pushed down against theseating element 323 and the sealedorifice 322. Simultaneously, and while the slot-pin mechanism 358 may be at least initially disengaged, theupper stem component 308 is forced downwards, and thespring element 316 is compressed until theupper bellows 310 are fully compressed and the downwards movement is physically stopped, illustrated by the ultimately closed valve configuration depicted inFIG. 3A . - As described above, during gas lift operations when the
annulus 16 is pressurized with injection gas, the injection gas may enter the valve from the annulus and pressurize variablevolume valve chamber 326. The valve may be configured such that pressurized injection gas in the variablevolume valve chamber 326 opposes the biasing force by imparting an upwards force directly upon theupper stem component 308. - An additional upwards force may, at times, be contributed by gas present in the
exit conduit 324 which may be a product of the gaseous environment in theproduction tubing 20. Gas in the exit conduit may create a tubing pressure which may be directly imparted on thelower stem component 318 primarily when the valve is closed. Some of this upwards force may be transmitted to theupper stem component 308 through thespring element 316. For brevity, the combination of any tubing pressure and injection gas pressure affecting the upper stem component at a moment of time will be referred to herein as "injection gas pressure" or "injection gas pressure in the variable volume valve chamber," even though this may be a simplification of actual conditions. - When the injection gas pressure in the variable
volume valve chamber 326 is sufficiently high, this pressure may counteract and dominate the biasing force from the pressurizedvariable volume dome 314. Theupper stem component 308 may be initially raised in isolation by the injection gas pressure for a short distance, and thespring element 316 may expand upwards. This isolated upwards displacement may occur until thepin 354 engages the upper end of theslot 356. Alternatively, the valve may be configured such that theupper stem component 308 may rise in isolation until thespring element 316 is extended. - Thereafter, an engaged slot-
pin mechanism 358 or extendedspring element 316 may result in thelower stem component 318 being pulled upwards with theupper stem component 308 by the force of the injection pressure, thereby opening the valve for one-way flow of injection gas into theproduction tubing 20. This open position is depicted inFIG 3B . - As will be understood by descriptions below of example valve operations, the open position of
FIG. 3B may be the state when injection gas pressure in the valve is sustained above a pressure threshold such that it dominates over the biasing pressure. The pressure threshold may be the pressure above which the injection gas pressure forces overcome the opposing biasing force and first begin to raise theupper stem component 308. The pressure threshold may be a function of the pressure of the gas in thevariable volume dome 314 and other physical characteristics of the valve components. - The ultimately closed position of
FIG. 3A may be the equilibrium, steady-state configuration of the valve in the absence of injection gas (or when injection gas pressure in the valve is below the pressure threshold) such that the biasing forces dominate and force the valve closed. - The initially closed position of
FIG. 3C may, thus, not be a steady-state of the valve, despite theorifice 322 being sealed and theexit conduit 324 being blocked in this configuration. Rather, this condition may be only a transitory state of the valve as certain valve components transition from the open position to the ultimately closed position with theupper bellows 310 fully compressed. - Upwards and downwards movements of the
upper stem component 308 may be influenced by, and may occur in conjunction with, expansion and compression of theupper bellows 310 and the lower bellows 304. The bellows assemblies may be formed of bellows elements (e.g., a stack of washers or other metal discs) residing within a column of damping fluid. The bellows elements may be edge-welded together (e.g., the metal discs may be welded at both the inner diameter and the outer diameter, or the inner diameter of one bellows element may be welded to an inner surface of the next bellows element). The bellows assemblies may act as a compressible and resilient gas seal interface between the gas in thevariable volume dome 314 and any gas present in the valve, such as injection gas in the variablevolume valve chamber 326. - One end of the
upper bellows 310 may be coupled (e.g., welded) to a widenedhorizontal flange portion 312 of the upper stem component, which may act as a piston for thevariable volume dome 314. For other embodiments, theflange portion 312 may be a component separate from, but coupled to theupper stem component 308. The other end of theupper bellows 310 may be coupled to arigid bellows adapter 360. In this manner, when the biasing pressure is the dominant force, compression of the upper bellows may occur in conjunction with the downwards travel of theupper stem component 308. When injection gas pressure in the variablevolume valve chamber 326 is dominant, the upper bellows may expand upwards in conjunction with the travel of theupper stem component 308. - The lower bellows 304 may be coupled (e.g., welded) to a lower portion of the
upper stem component 308. One end of the lower bellows 304 may be coupled to a lowerhorizontal protrusion 350 of the upper stem component. The other end of the lower bellows may be coupled (e.g., welded) to therigid bellows adapter 360. In this manner, when theupper stem component 308 is raised, the lower bellows 304 may be contracted upwards. When theupper stem component 308 is pushed downwards, the lower bellows 304 may be expanded downwards. - The upper and
lower bellows lower stem components - The upper and
lower bellows fluid passage 370 routed through the upper stem component 308 (i.e., a portion of the upper stem component is hollow and forms a chamber, which may be filled with a fluid). The fluid passage may serve to transport damping fluid from one bellows assembly to the other, thereby preventing chatter in the bellows. Thefluid passage 370 may be configured such that when either the upper or lower bellows are compressed, damping fluid flows from the compressing bellows to the other bellows, which is expanding. Composed of a non-compressible fluid (e.g., silicone oil), the damping fluid protects the upper andlower bellows fluid passage 370. - The
lower stem component 318 may interact with theupper stem component 308 through thespring element 316. Thespring element 316 may be formed of a strong vertically-mounted spring disposed within the variablevolume valve chamber 326. Thespring element 316 may also be formed of any compressible medium or linkage exhibiting compressibility and resilience properties similar to those of a strong spring. Thespring element 316 may enable thelower stem component 318 to be pulled upwards or pushed downwards by forces imparted on theupper stem component 308 and distributed, though the spring element, to thelower stem component 318. Thespring element 316 may also serve to provide a buffering feature by preventing forces imparted on thelower stem component 318 from being fully distributed to the upper stem component 308 (when the slot-pin mechanism 358 is not engaged). In this manner, thespring element 316 may enable theupper stem component 308 to move downwards and towards thelower stem component 318 following initial valve closure, when downwards movement of the lower stem component and theball sealing element 320 is fully resisted by theseating element 323. - The upper and
lower stem components pin mechanism 358. Lower engagement of the slot-pin mechanism may enable the biasing force to be distributed from theupper stem component 308 to thelower stem component 318, at times resulting in the lower stem component being pushed downwards with the upper stem component. Upper engagement of the slot-pin mechanism 358 may result in thelower stem component 318 being pulled upwards by a rising upper stem component 308 (e.g., due to an injection gas pressure in the chamber 326). In this manner, when the dominant force raises or lowers theupper stem component 308, the upper and lower stem components may move in tandem. - The slot-
pin mechanism 358 may also be configured so as to be disengaged at initial valve closure. Through this disengagement, the slot-pin mechanism may further serve to prevent the physical stop force imparted on thelower stem component 318 from being distributed to theupper stem component 308. This situation may facilitate further downwards movement of theupper stem component 308 towards the stationarylower stem component 318, which in turn may enable continued compression of the upper bellows 310. - The slot-
pin mechanism 358 may include at least onepin 354, which may be a rigid extension of theupper stem component 308. The lower portion of theupper stem component 308 may extend into a cavity, shaft or other opening (not shown) in the top of thelower stem component 318. Each of thepins 354 may extend into a vertically orientedslot 356 within thelower stem component 318. With thepin 354 not in contact with the upper or lower edge of theslot 356, theupper stem component 308 may move vertically without engaging the slot-pin mechanism 358, and without transmitting force through the pin to thelower stem component 318. - However, upwards movement of the
upper stem component 308 may eventually result in thepin 354 contacting the upper slot edge, causing the slot-pin mechanism 358 to engage. Continued upwards displacement of theupper stem component 308 past this point of upper engagement may result in thelower stem component 318 being pulled along by theupper stem component 308. From an unengaged position, downwards displacement of theupper stem component 308 may result in thepin 354 contacting the lower slot edge, causing the slot-pin mechanism 358 to engage. Continued downwards displacement by the biasing force of theupper stem component 308 past this point of lower engagement may result in thelower stem component 318 being pushed along with theupper stem component 308. - An upper portion of the
lower stem component 318 may be configured to fit within a cavity in the bottom portion of theupper stem component 308. In this configuration, when thepin 354 is not engaged, upwards and downwards movement of theupper stem component 308 relative to thelower stem component 318 may alter the portion of thelower stem component 318 which is surrounded by the upper stem component. - The variable
volume valve chamber 326 may be configured to include the space between thelower stem component 318 and therigid valve housing 328, as well as a cylindrical volume of space containing thespring element 316. Thehorizontal protrusion 350 of theupper stem component 308 may encapsulate the variablevolume valve chamber 326 from above. In this way, thehorizontal protrusion 350 may enable the force of injection gas in the variablevolume valve chamber 326 to be directly imparted upon theupper stem component 308, and to raise the upper stem component when that force is dominant. Thus, the encapsulation of the variablevolume valve chamber 326 by the horizontal protrusion may enable the valve chamber to expand in conjunction with upwards displacement of theupper stem component 308 at times when the injection gas pressure is dominant. When the biasing pressure is dominant, the variablevolume valve chamber 326 may contract in conjunction with downwards displacement of theupper stem component 308. - The
variable volume dome 314 may also be configured to expand and contract based on the dominant gas pressure force in the valve. Furthermore, thevariable volume dome 314 may be hermetically sealed, thereby enabling the mass of pressurized gas in the variable volume dome to be maintained at a constant or near-constant level. A horizontal flange portion 312 (of the upper stem component 308) may provide a variable, encapsulating lower surface of-and may act as a piston for-the variable volume dome. Theflange portion 312 may be urged to move up or down with theupper stem component 308, depending on the dominant gas pressure force in thevalve 300. Downwards displacement of theupper stem component 308 expands thevariable volume dome 314, while upwards displacement contracts the dome. - So that operations of
gas lift valve 300 may be understood in greater detail, the following paragraphs will describe an example sequence of valve operations. Because it is common for gas lift valves to be in the ultimately closed position before gas lift operations begin, this configuration will be described first. - With the valve in the ultimately closed position of
FIG. 3A , high pressure gas may be injected into theannulus 16 when gas lift operations commence. Upon reaching the subsurface depth at which thegas lift valve 300 is disposed, the pressurized injection gas may enter the valve through theentrance port 302 and flow into the variablevolume valve chamber 326, thereby increasing the valve chamber pressure. - If pressure in the variable
volume valve chamber 326 increases sufficiently to overcome the biasing force exerted by thevariable volume dome 314, the upwards pressure exerted on thehorizontal protrusion 350 may initially lift theupper stem component 308 in isolation, while thelower stem component 318 may remain in position against the seating element (as a result of compression of thesprint element 316 and/or the contemporary disengagement of the slot-pin mechanism 358). The isolated lifting of the upper stem component may cause thespring element 316 to expand and may raise thepin 354 in theslot 356 until the pin reaches the upper edge of the slot. Thereafter, further raising of theupper stem component 308 may pull the lower stem component upwards by way of the engaged slot-pin mechanism 358 and/or the spring element, thereby lifting theball sealing element 320 out of theorifice 322 and opening the valve for the passage of injected gas, as illustrated inFIG. 3B . Thereafter, and for as long as the valve remains open, pressurized gas may continuously flow freely from theannulus 16, through theentrance port 302, into the variablevolume valve chamber 326, through theexit conduit 324, out of theexit port 325, and into theproduction tubing 20. - The upwards movement of the
upper stem component 308 may also result in expansion of the variablevolume valve chamber 326 and theupper bellows 310, as well as contraction of thevariable volume dome 314 and compression of the lower bellows 304. Accordingly, the upper bellows may be extended in the open valve configuration. This expansion of theupper bellows 310 may be understood by comparison of the larger height of the upper bellows hupper-o inFIG. 3B to the smaller height hupper-uc of the upper bellows inFIG. 3A . - After a certain amount of upwards travel of the
upper stem component 308 andlower stem component 318, the lower bellows 304 may be fully compressed and may then retard the upwards travel of theupper stem component 308. The compression of the lower bellows 304 may be understood by comparison of the smaller height of the lower bellows hlower-o inFIG. 3B to the greater height of the lower bellows hlower-uc inFIG. 3A . - The resulting open position of the valve is depicted in
FIG. 3B. FIG. 3B depicts that the orifice 322 (and hence, the exit conduit 324) may be unobstructed by theball sealing element 320, which may be temporarily disposed above and clear of the orifice. The upper bellows 310 may be in an expanded state, and thevariable volume dome 314 may be in a contracted state resulting from the previous upwards travel of theupper stem component 308 and associatedhorizontal flange portion 312. As shown, thespring element 316 may be in an uncompressed state, and thepin 354 may be in a position at or near the top edge of theslot 356. Thevalve 300 may remain in this open position for as long as the injection pressure in the variablevolume valve chamber 326 is sufficient to resist the biasing force of the pressurized gas in thevariable volume dome 314. - When the pumping of injection gas into the
annulus 16 ceases, the injection pressure in the variablevolume valve chamber 326 may diminish. If injection pressure drops below the pressure threshold, the biasing pressure may once again become dominant and may initially drive theupper stem component 308 and thelower stem component 318 downwards, with thelower stem component 318 being pushed by theupper stem component 308 via thespring element 316. The downwards movement of theupper stem component 308 may be accompanied by compression of theupper bellows 310, expansion of the lower bellows 304, expansion of thevariable volume dome 314, and contraction of the variablevolume valve chamber 326. - This tandem downwards movement may persist until the preliminary closed position is reached when the
ball sealing element 320 contacts theseating element 323 and closes off theorifice 322, sealing the valve. The disposition of the gas lift valve components at initial closure is depicted inFIG. 3C . - As depicted in
FIG. 3C , when the valve reaches the initially closed position, thelower stem component 318 may again be physically prevented from moving downwards by rigid contact between theball sealing element 320 and theseating element 323. As a result of the previous downwards displacement of theupper stem component 308, the upper bellows 310 and the lower bellows 304 may be partially compressed and partially expanded, respectively. The partial compression of theupper bellows 310 at the point of initial valve closure may be understood by comparing the smaller height of the upper bellows hupper-ic inFIG. 3C to the larger height hupper-o of the upper bellows inFIG. 3B . The partial expansion of the lower bellows 304 may be understood by comparing the greater height of the lower bellows hlower-ic inFIG. 3C to the smaller height of the lower bellows hlower-o inFIG. 3B . - When the valve components reach the initially closed position, the
pin 354 may be positioned between the upper and lower edges of theslot 356, resulting in disengagement of the slot-pin mechanism 358. Thespring element 316 may therefore be (further) compressed in response to the resistance of the physical stop imparted on thelower stem component 318 and the continued downwards biasing force imparted on theupper stem component 308. In this way, thespring element 316 may enable continued downwards movement of theupper stem component 308 by buffering the upper stem component from the force of the physical stop being imparted on the lower stem component. - Consequently, the biasing force may continue to push the
upper stem component 308 downwards towards the stagnatedlower stem component 318. The downwards movement of theupper stem component 308 towards thelower stem component 318 may also cause thepin 354 to move downwards in theslot 356. - This additional downwards movement of the
upper stem component 308 may further compress theupper bellows 310 and further expand the lower bellows 304. The downwards movement may continue for so long as the biasing force is sufficient to overcome the upwards forces resulting from the increasing resistance of thecompressed spring element 316 or until theupper bellows 310 are fully compressed to solid. - By allowing the
upper stem component 308 to continue moving independently of the jammedlower stem component 318, the valve is prevented from stagnating in a steady-state, closed configuration which leaves theupper bellows 310 partially compressed and thus vulnerable to material degradation. Without thespring element 316 and/or another compressible joining mechanism capable of preventing the mechanical stop force from being fully imparted onto theupper stem component 308, the mechanical stop would result in this stagnated steady-state, closed configuration. - Valves that exhibit this stagnation may place unnecessary material strain on the upper bellows because the mechanical stop prevents complete bellows compression while the biasing force is still being exerted on the upper bellows. Thus, the upper bellows would endure this compression force despite being in a partially compressed state. In such a state, the bellows may be expected to exhibit poorer material durability and be subject to more rapid material failure, as compared to the structural solidity exhibited when the bellows are fully compressed.
- Returning now to
FIG. 3C , continued downwards movement of theupper stem component 308 and compression of theupper bellows 310 beyond the initially closed state ofFIG. 3C may eventually be restricted when theupper bellows 310 reach a fully compressed (or near fully compressed) state. The resulting valve configuration may be the ultimately closed configuration depicted inFIG. 3A and described above. The ultimately closed configuration of the valve may be characterized in that thespring element 316 may be at least partially compressed. Furthermore, due to the continued physical stop imparted on theball sealing element 320 and thelower stem component 318, the position of the lower stem component may be unchanged from its position at the time of initial closure. -
FIG. 3A further illustrates that, relative to the initially closed configuration ofFIG. 3C , theupper stem component 308 may be at a lower position in the valve. As described previously, this component may be driven to this lower position during the valve's transition to the ultimately closed configuration by the continued downwards force of the biasing pressure. The lower position of theupper stem component 308 relative to its position at initial closure may be a consequence of previous buffering provided by downwards compression of thespring element 316 against the physically stoppedlower stem component 318. - Furthermore, the upper bellows 310 are shown in a state of compression that is greater than the upper bellows compression depicted in
FIG. 3C . This enhanced compression may also be a consequence of the biasing force, buffering of the spring element, and the resultant continued downwards movement of the upper stem component subsequent to the initially closed configuration. Thus, as depicted inFIG. 3A , the compression of theupper bellows 310 may be a result of the compression of thespring element 316 subsequent to the initially closed configuration. Accordingly, thespring element 316 is depicted in a state of increased compression relative to the depiction of the spring element inFIG. 3C . Additionally, the lower bellows 304 may be in an extended state. - This enhanced compression of the
upper bellows 310 in the ultimately closed valve configuration may be understood by comparison of the larger height of the upper bellows hupper-ic inFIG. 3C to the smaller height hupper-uc of the upper bellows inFIG. 3A . The extension of the lower bellows 304 in the ultimately closed valve configuration may be understood by comparison of the smaller height of the lower bellows hlower-ic inFIG. 3C to the greater height of the lower bellows hlower-uc inFIG. 3A . -
FIG. 4 is a flow diagram ofexample operations 400 for performing downhole gas lift, in accordance with aspects of the present disclosure. Theoperations 400 may begin, at 402, by providing a valve. The valve generally includes a housing having an inlet and an outlet for fluid flow; a seat disposed in the housing for controlling the fluid flow from the inlet to the outlet; a stem configured to move in the housing, wherein a sealing element associated with the stem is configured to mate with an orifice in the seat to prevent the fluid flow from the inlet to the outlet, thereby closing the valve; first bellows coupled to the housing and to the stem; and second bellows coupled to the housing and to a movable piston of a variable volume dome in the housing, wherein the second bellows are fully compressed when the valve is closed. - At 404, the valve may be opened by injecting gas downhole. An injected gas pressure may be greater than a dome gas pressure in the variable volume dome, such that the stem moves away from the seat to allow the fluid flow between the inlet and the outlet via the orifice. For certain aspects, injecting the gas downhole compresses the first bellows.
- At 406, the operations may further include closing the valve by discontinuing to inject the gas downhole. The dome gas pressure may be greater than an external gas pressure external to the housing, such that the stem moves and the sealing element mates with the orifice in the seat.
- While the foregoing is directed to embodiments of the present disclosure, other and further embodiments may be devised without departing from the basic scope thereof, and the scope thereof is determined by the claims that follow.
- It will be appreciated that any of the aforementioned apparatus may have other functions in addition to the mentioned functions, and that these functions may be performed by the same apparatus.
- The applicant hereby discloses in isolation each individual feature described herein and any combination of two or more such features, to the extent that such features or combinations are capable of being carried out based on the present specification as a whole in the light of the common general knowledge of a person skilled in the art, irrespective of whether such features or combinations of features solve any problems disclosed herein, and without limitation to the scope of the claims. The applicant indicates that aspects of the present invention may consist of any such individual feature or combination of features. It should be understood that the embodiments described herein are merely exemplary and that various modifications may be made thereto without departing from the scope of the invention.
Claims (15)
- A valve for downhole gas lift operations, comprising:a housing having an inlet and an outlet for fluid flow;a seat disposed in the housing for controlling the fluid flow from the inlet to the outlet;a stem configured to move in the housing, wherein a sealing element associated with the stem is configured to mate with an orifice in the seat to prevent the fluid flow from the inlet to the outlet, thereby closing the valve;first bellows coupled to the housing and to the stem; andsecond bellows coupled to the housing and to a movable piston of a variable volume dome in the housing, wherein the second bellows are fully compressed when the valve is closed.
- The valve of claim 1, wherein the sealing element comprises a ball disposed at a tip of the stem.
- The valve of claim 1 or 2, wherein the stem comprises a first stem component and a second stem component mechanically coupled to the first stem component, and wherein the first and second stem components are configured to move in relation to one another.
- The valve of claim 3, wherein the first stem component has a slot and wherein the second stem component has a pin configured to travel within the slot as the first or the second stem component moves in relation to the other stem component.
- The valve of claim 3 or 4, wherein the first and second stem components are mechanically coupled by a spring.
- The valve of any of claims 3 to 5, wherein a portion of the second stem component is hollow and is filled with a non-compressible fluid for protecting at least one of the first or second bellows from gas pressures.
- The valve of claim 6, wherein the non-compressible fluid comprises silicone oil.
- The valve of any of claims 3 to 7, wherein the first stem component is mechanically stopped by the seat when the sealing element mates with the orifice and wherein the second stem component is configured to continue moving in relation to the first stem component until the second bellows are fully compressed.
- The valve of any preceding claim, wherein the valve is configured to operate in external pressures of at least 10 000 psi.
- A method for performing downhole gas lift operations, comprising:providing a valve, comprising:a housing having an inlet and an outlet for fluid flow;a seat disposed in the housing for controlling the fluid flow from the inlet to the outlet;a stem configured to move in the housing, wherein a sealing element associated with the stem is configured to mate with an orifice in the seat to prevent the fluid flow from the inlet to the outlet, thereby closing the valve;first bellows coupled to the housing and to the stem; andsecond bellows coupled to the housing and to a movable piston of a variable volume dome in the housing, wherein the second bellows are fully compressed when the valve is closed; andopening the valve by injecting gas downhole, wherein an injected gas pressure is greater than a dome gas pressure in the variable volume dome, such that the stem moves away from the seat to allow the fluid flow between the inlet and the outlet via the orifice.
- The method of claim 10, further comprising closing the valve by discontinuing to inject the gas downhole, wherein the dome gas pressure is greater than an external gas pressure external to the housing such that the stem moves and the sealing element mates with the orifice in the seat.
- The method of claim 10 or 11, wherein the stem comprises a first stem component and a second stem component mechanically coupled to the first stem component, and wherein the first and second stem components are configured to move in relation to one another.
- The method of claim 12, wherein the first stem component is mechanically stopped by the seat when closing the valve and wherein the second stem component continues to travel until the second bellows are fully compressed.
- The method of any of claims 10 to 13, wherein injecting the gas downhole compresses the first bellows.
- The method of any of claims 10 to 14, wherein the sealing element comprises a ball disposed at a tip of the stem.
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
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US201261650632P | 2012-05-23 | 2012-05-23 |
Publications (2)
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EP2666957A2 true EP2666957A2 (en) | 2013-11-27 |
EP2666957A3 EP2666957A3 (en) | 2015-04-29 |
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ID=48468177
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
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EP20130168990 Withdrawn EP2666957A3 (en) | 2012-05-23 | 2013-05-23 | Gas lift valve with ball-orifice closing mechanism and fully compressible dual edge-welded bellows |
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US (1) | US20130312833A1 (en) |
EP (1) | EP2666957A3 (en) |
Cited By (5)
Publication number | Priority date | Publication date | Assignee | Title |
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WO2020167521A1 (en) * | 2019-02-12 | 2020-08-20 | Baker Hughes Oilfield Operations Llc | Artificial lift system for a resource exploration and recovery system |
WO2022170336A1 (en) * | 2021-02-08 | 2022-08-11 | Baker Hughes Oilfield Operations Llc | Variable orifice valve for gas lift mandrel |
US11692405B2 (en) | 2021-02-10 | 2023-07-04 | Baker Hughes Oilfield Operations Llc | Guide sleeve for use with side pocket mandrel |
US11725490B2 (en) | 2020-11-11 | 2023-08-15 | Baker Hughes Oilfield Onerations LLC | Gas lift side pocket mandrel with modular interchangeable pockets |
US11933150B2 (en) | 2021-01-14 | 2024-03-19 | Baker Hughes Oilfield | Electric remote operated gas lift mandrel |
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US9057255B2 (en) * | 2011-10-11 | 2015-06-16 | Weatherford Technology Holdings, Llc | Dual flow gas lift valve |
US9605521B2 (en) * | 2012-09-14 | 2017-03-28 | Weatherford Technology Holdings, Llc | Gas lift valve with mixed bellows and floating constant volume fluid chamber |
US9518674B2 (en) | 2014-03-07 | 2016-12-13 | Senior Ip Gmbh | High pressure valve assembly |
US9519292B2 (en) | 2014-03-07 | 2016-12-13 | Senior Ip Gmbh | High pressure valve assembly |
EP3224448B1 (en) | 2014-11-24 | 2020-07-29 | Senior IP GmbH | High pressure valve assembly |
US20190211657A1 (en) * | 2018-01-11 | 2019-07-11 | Weatherford Technology Holdings, Llc | Side pocket mandrel for gas lift and chemical injection operations |
US10787889B2 (en) * | 2018-07-26 | 2020-09-29 | Weatherford Technology Holdings, Llc | Gas lift valve having shear open mechanism for pressure testing |
US20230258061A1 (en) * | 2022-02-14 | 2023-08-17 | Trc Services, Inc. | Gas Lift Valve Remanufacturing Process and Apparatus Produced Thereby |
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US2797700A (en) * | 1953-08-07 | 1957-07-02 | Camco Inc | Balanced flow valve |
US3363581A (en) * | 1966-05-16 | 1968-01-16 | Kelley Kork | Gas lift valve |
US6932581B2 (en) * | 2003-03-21 | 2005-08-23 | Schlumberger Technology Corporation | Gas lift valve |
NO328257B1 (en) * | 2008-03-13 | 2010-01-18 | Petroleum Technology Co As | Bellow valve 2 |
US9010353B2 (en) * | 2011-08-04 | 2015-04-21 | Weatherford Technology Holdings, Llc | Gas lift valve having edge-welded bellows and captive sliding seal |
US9057255B2 (en) * | 2011-10-11 | 2015-06-16 | Weatherford Technology Holdings, Llc | Dual flow gas lift valve |
-
2013
- 2013-05-22 US US13/900,114 patent/US20130312833A1/en not_active Abandoned
- 2013-05-23 EP EP20130168990 patent/EP2666957A3/en not_active Withdrawn
Non-Patent Citations (1)
Title |
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Cited By (8)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2020167521A1 (en) * | 2019-02-12 | 2020-08-20 | Baker Hughes Oilfield Operations Llc | Artificial lift system for a resource exploration and recovery system |
US11060385B2 (en) | 2019-02-12 | 2021-07-13 | Baker Hughes Oilfield Operations Llc | Artificial lift system for a resource exploration and recovery system |
US11725490B2 (en) | 2020-11-11 | 2023-08-15 | Baker Hughes Oilfield Onerations LLC | Gas lift side pocket mandrel with modular interchangeable pockets |
US11933150B2 (en) | 2021-01-14 | 2024-03-19 | Baker Hughes Oilfield | Electric remote operated gas lift mandrel |
WO2022170336A1 (en) * | 2021-02-08 | 2022-08-11 | Baker Hughes Oilfield Operations Llc | Variable orifice valve for gas lift mandrel |
US11542798B2 (en) | 2021-02-08 | 2023-01-03 | Baker Hughes Oilfield Operations Llc | Variable orifice valve for gas lift mandrel |
GB2618475A (en) * | 2021-02-08 | 2023-11-08 | Baker Hughes Oilfield Operations Llc | Variable orifice valve for gas lift mandrel |
US11692405B2 (en) | 2021-02-10 | 2023-07-04 | Baker Hughes Oilfield Operations Llc | Guide sleeve for use with side pocket mandrel |
Also Published As
Publication number | Publication date |
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US20130312833A1 (en) | 2013-11-28 |
EP2666957A3 (en) | 2015-04-29 |
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