EP1916380A1 - Verfahren und System zum Entfernen von Flüssigkeit aus einem Erdgasbohrloch - Google Patents

Verfahren und System zum Entfernen von Flüssigkeit aus einem Erdgasbohrloch Download PDF

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Publication number
EP1916380A1
EP1916380A1 EP06255476A EP06255476A EP1916380A1 EP 1916380 A1 EP1916380 A1 EP 1916380A1 EP 06255476 A EP06255476 A EP 06255476A EP 06255476 A EP06255476 A EP 06255476A EP 1916380 A1 EP1916380 A1 EP 1916380A1
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EP
European Patent Office
Prior art keywords
plunger
limiting means
liquid
production tubing
lift system
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Ceased
Application number
EP06255476A
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English (en)
French (fr)
Inventor
designation of the inventor has not yet been filed The
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
BP Exploration Operating Co Ltd
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BP Exploration Operating Co Ltd
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by BP Exploration Operating Co Ltd filed Critical BP Exploration Operating Co Ltd
Priority to EP06255476A priority Critical patent/EP1916380A1/de
Priority to PCT/GB2007/003997 priority patent/WO2008050095A1/en
Priority to AT07824246T priority patent/ATE479823T1/de
Priority to DE602007008930T priority patent/DE602007008930D1/de
Priority to US12/312,002 priority patent/US20090321083A1/en
Priority to EP07824246A priority patent/EP2076654B1/de
Priority to EA200900508A priority patent/EA015024B1/ru
Publication of EP1916380A1 publication Critical patent/EP1916380A1/de
Ceased legal-status Critical Current

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK 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
    • E21B43/13—Lifting well fluids specially adapted to dewatering of wells of gas producing reservoirs, e.g. methane producing coal beds
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04B—POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS
    • F04B47/00—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps
    • F04B47/12—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having free plunger lifting the fluid to the surface

Definitions

  • the present invention relates to a method and system for removing liquid from gas wells.
  • Liquids may occur in gas wells as a result of condensation, which takes place when the reservoir pressure is insufficient for particular components to remain in the gaseous state; such components are known as "condensables" and include water, propane, butane, pentane, propylene, ethylene and acetylene.
  • condensables include water, propane, butane, pentane, propylene, ethylene and acetylene.
  • a further source of liquids in gas wells may be water encroachment into the gas producing formation from aquifers or other water-bearing zones.
  • Gas wells which produce liquids are susceptible to liquid loading, whereby a liquid column accumulates at the bottom of the well.
  • Liquid loading takes place when the flow rate of the produced gas is insufficient to naturally carry liquids to the surface. Liquids are naturally carried to the surface both as entrained droplets and as a liquid film on the inner surface of the production tubing.
  • gas flow rate also decreases. If the flow rate drops below the minimum flow rate at which liquids can be lifted out of a particular well by the flowing gas stream - the critical velocity - fall back of liquid occurs and liquid loading begins.
  • Gas wells which experience liquid loading may be low pressure wells, which may sustain liquid loading as soon as production commences.
  • gas wells which undergo liquid loading may be depleted wells, in which the gas flow rate had initially been sufficient to carry liquids to the surface naturally and where production of gas from the gas well has resulted in the reservoir pressure decreasing to such an extent that liquid loading has commenced.
  • plunger lift is a cyclic operation wherein a plunger (i.e. a piston) moves reciprocally between two longitudinal positions within a well-production tubing, typically between the lower end of the well production-tubing and a position immediately below, at or immediately above the wellhead.
  • a plunger i.e. a piston
  • the plunger travels from the lower end of the production tubing towards the wellhead under the propulsion of gas which has built up in the well and below the plunger. Gas may build up in the well naturally, or may be injected into the well from the surface.
  • the well is shut-in (i.e. production is stopped) thereby providing an enclosed system and the plunger is allowed to fall through the production tubing under the influence of gravity.
  • the plunger reaches a column of liquid at the lower end of the production tubing the liquid bypasses the plunger via an annulus between the plunger and the inner-surface of the production tubing and/or through a longitudinal channel through the plunger and accumulates above the plunger.
  • the well is then put back into production, and the pressure that has built up below the plunger lifts the plunger and the liquid column towards the wellhead.
  • the annulus between the plunger and the inner surface of the tubing is such that although liquid bypass is tolerated when the plunger falls through the liquid column, on lift of the plunger there is sufficient gas turbulence in the annulus to create a liquid seal which prevents, at least to some extent, fallback of liquid from above the plunger.
  • Two-piece plungers may be employed in a plunger lift system.
  • Two-piece plungers are particularly common.
  • Two-piece plungers comprise two members which, when coupled together, are capable of lifting liquids.
  • the two members of the plunger are capable of independently falling through an upwardly moving stream of gas or a multiphase stream of gas and liquid without substantially impeding the upward flow of the stream.
  • a two-piece plunger can be dropped into a gas well whilst the well is in production, thereby reducing the period for which the well must be shut in, or eliminating the need for shutting in the well. This may significantly speed up plunger lift cycles.
  • a surfactant or mixture of surfactants may be injected into a gas well to form a foam, which reduces the surface tension of the liquid such that the foam may be lifted at a lower critical velocity than is required for lifting the "un-foamed” liquid.
  • surfactants are useful in de-watering gas wells, liquid hydrocarbons do not foam well and the produced liquid may require continual agitation to maintain foaming.
  • a disadvantage of injecting a surfactants or mixture of surfactants into a gas well is the cost of the chemicals and potential technical problems associated with the deployment of these chemicals. Also, the installation of a permanent injection facility can be costly and technically challenging.
  • batch treating dumping surfactant into a well adds to the hydrostatic liquid column resulting in a limited "time-window" in which the treatment is effective.
  • Plunger lift systems are advantageous because they can operate without the input of energy and their installation is relatively cheap. In addition, there are methods available to determine whether plunger lift will work in a particular well prior to installation. Also, if, for some reason, a plunger lift system fails to work, it can be relatively easily removed from the well by, for example, wireline retrieval methods.
  • Existing plunger lift systems do, however, suffer from at least one significant disadvantage: since the plunger must be able to move between the lower and upper limiting means, the production tubing that is run into the well must not comprise any restrictions which would prevent this. Thus, existing plunger lift systems may not be employed in any gas well where the production tubing has such a restriction. Such restrictions may include down-hole valves, or narrowing of the production tubing. In particular, existing plunger lift systems may not be employed in gas wells where a sub-surface safety valve is present in the production tubing.
  • a method of removing liquid from a gas well having a production tubing with a restriction therein run into the upper portion thereof and wherein a plunger lift system in arranged within the production tubing, the plunger lift system comprising an upper limiting means, a lower limiting means, a plunger that is capable of moving between the upper and lower limiting means, and a one-way valve situated at or above the upper limiting means that is capable of allowing fluid passage therethrough in an upward direction but not in a downward direction; the method comprising the steps of:
  • gas pressure may also build up, in step c), in the annulus between the production tubing and the casing of a cased gas well.
  • the method of the present invention may be employed in a deviated well provided that the angle of deviation of the well from the vertical is less than 60°, preferably less than 30°, such that the plunger is capable of falling under gravity through the production tubing.
  • the upper and lower limiting means are simply means which prevent the plunger travelling further than required. However, it is preferred that the upper and lower limiting means do not impede fluid flow in the production tubing.
  • the one way-valve may be situated either above or below the restriction in the production tubing, preferably immediately below the restriction. It is also envisaged that the one-way valve may be situated at the upper limiting means, and may in fact act as the upper limiting means. Where the restriction in the production tubing is a downhole valve, such as a sub-surface safety valve of an off-shore gas well, the one-way valve may be incorporated into the downhole valve. Accordingly, the downhole valve may be the restriction in the production tubing and also act as the upper limiting means and as the one-way valve; this provides for relatively easy access if maintenance is required.
  • the volume of the column of liquid that forms in the production tubing above the lower limiting means is substantially greater than the volume of the production tubing between the upper limiting means and the one way-valve such that the plunger forces a substantial portion of the column of liquid through the one-way valve. It is therefore preferred that the one-way valve lies immediately above the upper limiting means.
  • the plunger forces at least 75% of the column of liquid through the one-way valve, preferably, at least 95%.
  • the lower limiting means is located within the production tubing at or near the lower end thereof.
  • step (a) the gas well is in production.
  • a gas stream or a multiphase stream of gas and liquid is capable of by-passing the plunger that is retained at the upper limiting means via an annulus between the plunger and the inner surface of the production tubing.
  • the gas stream or multiphase stream then passes through the one-way valve and to the wellhead of the gas well.
  • the gas well is shut-in during step (b).
  • the gas well is opened-up during step (c).
  • the one-way valve of the plunger lift system prevents the liquid that has been forced therethrough from falling back down the production tubing.
  • the volume of gas increases with decreasing depth due to expansion of the gas at lower pressures. Accordingly, the velocity of the gas that has passed through the one way valve may be higher than the velocity of gas in the lower end of the production tubing. This can lead to the phenomenon that, in upper parts of a gas well, the velocity of the gas may exceed the critical velocity. Where the velocity of the gas stream or of the multiphase stream that passes through the one-way valve is above the critical velocity, liquid will be naturally lifted from above the one-way valve to the wellhead.
  • liquid will accumulate above the one-way valve. Initially, this liquid may be sufficiently agitated to allow for the passage of gas. However, artificial lift may eventually be required to remove the liquid that accumulates in the production tubing above the one-way valve. Owing to the potential increased velocity of the gas stream or the multiphase stream above the one way valve and/or the decreased distance to lift the liquid, the chosen method of artificial lift that is employed is likely to be more effective and/or economical when used in combination with the method of the present invention than if that artificial lift method was used alone to lift liquid from the lower end of the production tubing.
  • the method of the present invention may further comprise the step of artificially lifting liquid that accumulates in the production tubing above the one-way valve to the wellhead of the gas well.
  • a surfactant or a mixture of surfactants may be added to any liquid which accumulates above the one-way valve thereby forming a foam which is lifted to the wellhead by the flow of the gas stream or multiphase stream that passes through the one way valve.
  • a further plunger lift system may be employed to lift any liquid that accumulates in the production tubing above the one way valve. Accordingly, the method of the present invention may further comprise the following steps:
  • the gas well is shut-in during step (g).
  • the gas well is opened-up during step (h).
  • an apparatus for removing liquids from a gas well having a production tubing with a restriction therein run into the upper portion thereof comprising a plunger lift system arranged within the production tubing wherein the plunger lift system comprises: an upper limiting means, a lower limiting means, a plunger that is capable of moving between the upper and lower limiting means, and a one-way valve that is capable of allowing fluid passage therethrough in an upward direction but not in a downward direction characterised in that the one-way valve is situated at or above the upper limiting means, the upper limiting means is situated at or below the restriction in the production tubing, and the lower limited means is situated at location where, during production of gas from the gas well, a column of liquid accumulates in the production tubing.
  • the upper limiting means of the plunger lift system is preferably the restriction in the production tubing.
  • the upper limiting means may be a separate restriction within the production tubing.
  • the plunger lift system may further comprise a retaining means for holding the plunger at or near the upper limiting means until it is required to fall.
  • a retaining means may be a mechanically or electrically actuated retaining-means, controllable from the surface.
  • the upper limiting means may comprise an electromagnetic retaining means, also controllable from the surface. Electricity may be supplied to such retaining means by batteries, or by an electrical cable run, for example, through an annulus between the production tubing and the well-casing and then through the wall of the production tubing.
  • the plunger lift system may further comprise a means for detecting when the volume of the column of liquid (liquid loading) is sufficiently high that the plunger is required to fall towards the lower limiting means and through the column of liquid until it engages with the lower limiting means.
  • Such means may, for example, be a pressure measurement device, located at the lower limiting means, wherein the pressure measurement is correlated with liquid loading.
  • the plunger lift system may further comprise means for detecting when the plunger has reached the lower limiting means.
  • Such means include, for example, electro-magnetic detectors, impact detectors, and acoustic detectors.
  • the one-way valve may be situated above or below the restriction in the production tubing.
  • the one-way valve is situated below the restriction. More preferably the one-way valve acts as the upper limiting means. Also, as discussed above, the one-way valve may act as the restriction in the production tubing.
  • the plunger lift system may further comprise shock absorber means for absorbing shock when the plunger impacts upon the lower and upper limiting means.
  • the shock absorber means may act as the upper and/or lower limiting means.
  • the upper and/or lower limiting means may be a resilient bumper, such as a bumper spring.
  • one or both of the shock absorbers may be attached, either directly or indirectly, to the plunger itself, for example a bumper spring may be attached to the upper and/or lower surfaces of the plunger.
  • the plunger of the plunger lift system is cylindrical in shape where the longitudinal axis of the cylinder is aligned with the longitudinal axis of the production tubing.
  • the plunger is composed of a dense material, such as galvanised titanium or steel.
  • the cylindrical surface of the plunger is provided with ribs or grooves in order to aid turbulence in the annulus between the plunger and the production tubing.
  • the cylindrical surface of the plunger is provided with circumferential or helical ribs or grooves.
  • the plunger of the plunger lift system of the present invention is a two-piece plunger.
  • Two-piece plungers generally comprise a cylindrical first member, having a channel extending longitudinally therethrough; and a second member, which sealingly engages with the cylindrical first member thereby sealing the channel, such that passage of fluids through the channel is either prevented or is substantially reduced.
  • the channel may be arranged centrally in the cylindrical first member or may be offset. It is preferred that the longitudinal axis of the channel is aligned with the longitudinal axis of the cylindrical first member.
  • the two-piece plunger is arranged in the production tubing with the longitudinal axis of the cylindrical first membrane aligned with the longitudinal axis of the production tubing.
  • the cylindrical first member is arranged above the second member in the production tubing.
  • the lower surface of the cylindrical first member is shaped to complement the shape of the second member, for example, the second member may be spherical and the lower surface of the cylindrical first member may be concave - this ensures that sealing engagement of the first and second members can be readily achieved.
  • the second member may be a rod which fits inside the channel of the cylindrical first member.
  • Such rods may be provided with stabilisers, for example a series of outwardly extending arms at the base of the rod, such that the rod remains aligned with the channel of the cylindrical first member.
  • the cylindrical first member of the two-piece plunger is held by retaining means at the upper limiting means while the second member falls down the production tubing toward the lower limiting means.
  • a gas stream or a multiphase stream of gas and liquid is able to flow upwardly around it.
  • the second member may be allowed to fall through the production tubing while the gas well remains in production.
  • the cylindrical first member may be released from the retaining means.
  • the cylindrical first member falls down the production tubing it allows upward flow of a gas stream or a multiphase stream of gas and liquid through the channel. Accordingly, the cylindrical first member may also be released from the retaining means while the gas well remains in production.
  • the upper limiting means is provided with a decoupling means for decoupling the sealingly-engaged first and second members of the two-piece plunger thereby unsealing the channel of the cylindrical first member. It is preferred that the decoupling means does not prevent upward passage of fluids through the channel of the cylindrical first member of the two-piece plunger.
  • the decoupling means protrudes downwardly from the upper limiting means and is capable of being inserted through the channel of the first member to decouple the two-piece plunger by forcing the second member away from sealing engagement with the channel of the cylindrical first member.
  • the downwardly protruding decoupling means is a pipe having a length greater than the length of the channel in the cylindrical first member.
  • the downwardly protruding decoupling means may be a rod, which is of narrower diameter than the channel and has a length that is greater than the length of the channel of the cylindrical first member.
  • the gas flow rate may be too high for the second member of the two piece plunger to fall through the production tubing.
  • the second member may be held by gas flow adjacent the channel through the cylindrical first member.
  • the second member does not block the channel, as the rod has forced the second member away from sealing engagement with the channel such that fluid can flow around the second member and through an annulus between the wall of the channel and the rod.
  • the downwardly protruding decoupling means is a pipe
  • the lower end of the pipe is shaped so as to mitigate the risk of the second member blocking the channel in the cylindrical first member to flow of fluid therethrough, for example, the lower end of the pipe may be cut at an angle, or there may be perforations in the lower end of the pipe.
  • the second member will fall toward the lower limiting means of the plunger lift system.
  • the apparatus of the present invention may comprise a further plunger lift system comprising an upper limiting means situated at or near the wellhead and a lower limiting means situated at or above the restriction within the production tubing and at or above the one-way valve.
  • the lower limiting means of the further plunger lift system is suitably the restriction.
  • the lower limiting means of the further plunger lift system is suitably the one-way valve.
  • the further plunger lift system additionally comprises a retaining means for holding the plunger at or near the upper limiting means.
  • the further plunger lift system also includes a means of detecting when sufficient liquid has accumulated above the one-way valve such that the plunger is required to fall.
  • a means of detecting when the plunger of the further plunger lift system has reached the lower limiting means is preferably provided.
  • the further plunger lift system may also comprise shock absorbing means, as described above.
  • the plunger of the further plunger lift system is a two-piece plunger of the type described above in which case, the upper limiting means of the further plunger lift system is provided with a decoupling means.
  • a corresponding number of plunger lift systems may be employed, for successively lifting liquid past each of the restrictions within the production tubing and to the wellhead.
  • the apparatus of the present invention comprises at least one further plunger lift system
  • the apparatus may further comprise a timing device.
  • a timing device may allow the plungers of the systems to be released at different times. This may prevent the unnecessary lifting of one of the plungers, in particular when a plunger has little, or no, liquid above it.
  • the apparatus comprises: a first and a second plunger lift system arranged within a production tubing (4) below and above a sub-surface safety valve (5) respectively.
  • the first plunger lift system comprises a plunger (1), an upper limiting means (2), a lower limiting means (3), and a one-way valve (6) situated above the upper limiting means (2) and below the sub-surface safety valve (5).
  • the second plunger lift system comprises a plunger (7), an upper limiting means (not shown) and a lower limiting means (8), situated above the sub-surface safety valve (5).
  • the plunger (1) of the first plunger lift system is a two-piece plunger comprising a cylindrical first member (1) and a spherical second member (9) wherein the cylindrical first member (1) has a channel (10) extending longitudinally therethrough and a concave lower surface (not shown).
  • the upper limiting means (2) of the first plunger lift system is provided with a decoupling means (11) for releasing the spherical second member (9) of the two-piece plunger from sealing engagement with the concave lower surface of the cylindrical first member.
  • the decoupling means (11) is a pipe that extends downwardly from the upper limiting means (2) and has its lower end cut at an angle.
  • a retaining means (not shown) - preferably a mechanical tool that is triggered by pressure - is provided for holding the first member of the two-piece plunger (1) at or near the upper limiting means (2).
  • the lower limiting means (3) of the first plunger lift system is optionally provided with a shock absorbing means.
  • the plunger (7) of the second plunger lift system is also a two-piece plunger (7), comprising a cylindrical first member (7) and a spherical second member (12) wherein the cylindrical first member (7) has a channel (13) extending longitudinally therethrough and a concave lower surface (not shown).
  • the upper limiting means (not shown) of the second plunger lift system is the wellhead or may be located near the wellhead and the upper limiting means is provided with a decoupling means (not shown), for example, a rod protruding downwardly from the wellhead; and a retaining means(not shown) for holding the first member of the two-piece plunger of the second plunger lift system at or near the upper limiting means (not shown) of the second plunger lift system.
  • the retaining means is a conventional lubricator type arrangement.
  • the lower limiting means (8) of the second plunger lift system is optionally provided with a shock-absorbing means.
  • a column of liquid (14) is allowed to accumulate above the lower limiting means (3) of the first plunger lift system while the cylindrical first member (1) of the two-piece plunger is held at the upper limiting means (2) by the retaining means (not shown).
  • the volume of the column of liquid (14) reaches a critical volume at which gas production declines to an unacceptable level, the gas well is generally shut-in and the first member (1) of the two-piece plunger is released from the retaining means (not shown) and is allowed to fall.
  • gas or a multiphase mixture of gas and liquid passes through the channel (10).
  • the two-piece plunger (1 & 9) of the first plunger lift system reaches the upper limiting means (2), the second member of the two-piece plunger (9) will be forced away from the first member (1) by the decoupling means (11) and the retaining means for holding the plunger at the upper limiting means (not shown) is actuated. If the gas flow rate is initially too high for the second member (9) of the two-piece plunger to fall, the angled end of the downwardly protruding pipe (11) will prevent the second member (9) of the two-piece plunger blocking the pipe (11) to passage of gas or multiphase fluid. As gas flow rate declines (for example due to further liquid loading) the second member (9) of the two-piece plunger will fall to the lower limiting means (3) of the first plunger lift system. The cycle may then be repeated.
  • Liquid which is lifted through the one-way valve (6) by the first plunger lift system will accumulate above the one-way valve as a liquid column (15). Once the volume of the liquid column (15) above the one-way valve (6) exceeds a certain critical volume at which gas production declines to an unacceptable level, the first member (7) of the two-piece plunger of the second plunger lift system is released from the retaining means (not shown) and allowed to fall.
  • the retaining means for holding the first member (7) at the well head (not shown) can be actuated and the protruding rod forces the spherical second member (12) of the two-piece plunger away from sealing engagement with the channel of the cylindrical first member, such that the second member (12) may fall to the lower limiting means (8).
  • the cycle may then be repeated.
  • the retaining means may be connected to a timer device (not shown) such that the first members (1 & 7) of the first and second plunger lift systems may be allowed to fall at different times.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
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  • Physics & Mathematics (AREA)
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  • Oil, Petroleum & Natural Gas (AREA)
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  • General Engineering & Computer Science (AREA)
  • Pipe Accessories (AREA)
  • Separation By Low-Temperature Treatments (AREA)
  • Electrical Discharge Machining, Electrochemical Machining, And Combined Machining (AREA)
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  • Physical Or Chemical Processes And Apparatus (AREA)
EP06255476A 2006-10-24 2006-10-24 Verfahren und System zum Entfernen von Flüssigkeit aus einem Erdgasbohrloch Ceased EP1916380A1 (de)

Priority Applications (7)

Application Number Priority Date Filing Date Title
EP06255476A EP1916380A1 (de) 2006-10-24 2006-10-24 Verfahren und System zum Entfernen von Flüssigkeit aus einem Erdgasbohrloch
PCT/GB2007/003997 WO2008050095A1 (en) 2006-10-24 2007-10-19 Method and apparatus for removing liquid from a gas well
AT07824246T ATE479823T1 (de) 2006-10-24 2007-10-19 Verfahren und vorrichtung zum entfernen von flüssigkeit aus einer gasbohrung
DE602007008930T DE602007008930D1 (de) 2006-10-24 2007-10-19 Verfahren und vorrichtung zum entfernen von flüssigkeit aus einer gasbohrung
US12/312,002 US20090321083A1 (en) 2006-10-24 2007-10-19 Method and apparatus for removing liquid from a gas well
EP07824246A EP2076654B1 (de) 2006-10-24 2007-10-19 Verfahren und vorrichtung zum entfernen von flüssigkeit aus einer gasbohrung
EA200900508A EA015024B1 (ru) 2006-10-24 2007-10-19 Способ и устройство для извлечения жидкости из газовой скважины

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
EP06255476A EP1916380A1 (de) 2006-10-24 2006-10-24 Verfahren und System zum Entfernen von Flüssigkeit aus einem Erdgasbohrloch

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EP1916380A1 true EP1916380A1 (de) 2008-04-30

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EP06255476A Ceased EP1916380A1 (de) 2006-10-24 2006-10-24 Verfahren und System zum Entfernen von Flüssigkeit aus einem Erdgasbohrloch
EP07824246A Not-in-force EP2076654B1 (de) 2006-10-24 2007-10-19 Verfahren und vorrichtung zum entfernen von flüssigkeit aus einer gasbohrung

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EP07824246A Not-in-force EP2076654B1 (de) 2006-10-24 2007-10-19 Verfahren und vorrichtung zum entfernen von flüssigkeit aus einer gasbohrung

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US (1) US20090321083A1 (de)
EP (2) EP1916380A1 (de)
AT (1) ATE479823T1 (de)
DE (1) DE602007008930D1 (de)
EA (1) EA015024B1 (de)
WO (1) WO2008050095A1 (de)

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EP2085572A2 (de) 2008-01-25 2009-08-05 Weatherford/Lamb, Inc. Kolbenhebesystem für Bohrloch
WO2011079218A3 (en) * 2009-12-23 2011-11-17 Bp Corporation North America Inc. Rigless low volume pump system
US8834133B2 (en) 2010-08-05 2014-09-16 Bp Corporation North America Inc. Pumping device for fluids located at the bottom of a drilled well
CN104820749A (zh) * 2015-05-12 2015-08-05 强艳玲 一种气井综合采气曲线及其分析方法
US10030490B2 (en) 2014-04-16 2018-07-24 Bp Corporation North America, Inc. Reciprocating pumps for downhole deliquification systems and fluid distribution systems for actuating reciprocating pumps

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US9664016B2 (en) 2013-03-15 2017-05-30 Chevron U.S.A. Inc. Acoustic artificial lift system for gas production well deliquification
US9587470B2 (en) * 2013-03-15 2017-03-07 Chevron U.S.A. Inc. Acoustic artificial lift system for gas production well deliquification
WO2015017220A1 (en) 2013-07-29 2015-02-05 Bp Corporation North America Inc. Systems and methods for producing gas wells with multiple production tubing strings
US9470076B2 (en) 2013-07-29 2016-10-18 Bp Corporation North America Inc. Systems and methods for production of gas wells
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EA015024B1 (ru) 2011-04-29
EP2076654A1 (de) 2009-07-08
EP2076654B1 (de) 2010-09-01
US20090321083A1 (en) 2009-12-31
WO2008050095A1 (en) 2008-05-02
DE602007008930D1 (de) 2010-10-14
ATE479823T1 (de) 2010-09-15
EA200900508A1 (ru) 2009-12-30

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