EP0818603A1 - Erdöl-Produktionseinrichtung und Verfahren - Google Patents

Erdöl-Produktionseinrichtung und Verfahren Download PDF

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Publication number
EP0818603A1
EP0818603A1 EP97401594A EP97401594A EP0818603A1 EP 0818603 A1 EP0818603 A1 EP 0818603A1 EP 97401594 A EP97401594 A EP 97401594A EP 97401594 A EP97401594 A EP 97401594A EP 0818603 A1 EP0818603 A1 EP 0818603A1
Authority
EP
European Patent Office
Prior art keywords
well
liquid
source
chamber
gas
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.)
Granted
Application number
EP97401594A
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English (en)
French (fr)
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EP0818603B1 (de
Inventor
Michel Iato
Alain Viard
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.)
Elf Exploration Production SAS
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Elf Exploration Production SAS
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Filing date
Publication date
Application filed by Elf Exploration Production SAS filed Critical Elf Exploration Production SAS
Publication of EP0818603A1 publication Critical patent/EP0818603A1/de
Application granted granted Critical
Publication of EP0818603B1 publication Critical patent/EP0818603B1/de
Anticipated expiration legal-status Critical
Expired - Lifetime legal-status Critical Current

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    • 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
    • E21B43/122—Gas lift
    • 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
    • E21B43/34—Arrangements for separating materials produced by the well
    • E21B43/38—Arrangements for separating materials produced by the well in the well

Definitions

  • the present invention relates to a pumping process a liquid effluent and, more particularly to a process pumping hydrocarbons from an oil well.
  • the present invention also relates to a pumping plant for petroleum effluent from from an underground source.
  • the natural flow of hydrocarbons from the bottom to the surface is insufficient for allow or maintain commercial production. This is due either to the high viscosity of the hydrocarbons, or to too low natural pressure at the bottom of the well, or still a combination of the two. Water inflows into the wells can also limit the natural flow of hydrocarbons.
  • a assistance system or well activation system By example, we can mount a pump at the lower end a production tube located in the well, where you can provide a gas injection system at the bottom of the well. The latter type of installation more commonly called "gas lift", used to lighten the column of hydrocarbons located in the well to facilitate its ascent to the surface.
  • Another assistance system consists in pumping the hydrocarbons made from the surface.
  • EP-A-579497 describes a method of pumping liquid from one end of a well to a outlet at the opposite end of the well, where regulates the gas pressure in one or more chambers so that they fill up with liquid. Then a pressure of superior gas is applied to each chamber in order to move the liquid and send it to the outlet.
  • Each chamber is fitted with controlled inlet and outlet valves from level sensors to control the direction liquid flow.
  • the rooms can either be overlaid on top of each other inside the well, either be arranged side by side in a point near the exit of the well.
  • the positioning of the chambers superimposed in the well has advantages in that it allows to have a less bulky installation and energy efficiency optimized.
  • this type of installation presents disadvantages since the superimposition of the rooms, each being provided with various valves and level detectors, requires one or more chambers to be removed from the well when there is a breakdown or failure in one of the lower rooms.
  • the use of multiple rooms, each equipped with valves and detectors levels makes maintenance forecasts difficult the installation.
  • the document US-A-1,499.509 describes a method of pumping a effluent from a weak eruptive oil well. According to this process, the effluent fills an annular space defined between the wall of the well and a production casing which extends from the bottom of the well to the surface. Once annular space filled with effluent, gas under pressure is sent from the surface into the upper end of this space, causing displacement of the effluent and its up to the surface from the inside of the casing.
  • the subject of the present invention is an installation for pumping allowing the implementation of the pumping process.
  • the invention proposes a installation for pumping a liquid from a source underground including a well extending from the surface towards the liquid source, the well comprising a chamber extending substantially over its entire length, at least a casing crossing the chamber and communicating with it, and a set of valves for selectively placing the room in communication with a gas source at a first pressure allowing the liquid from the source to fill the chamber, and a source of gas to a second pressure greater than the first pressure, in order to empty the chamber, the liquid being returned to a first outlet by flow through the casing, characterized in what it includes, in addition, a valve mounted in the casing , and a second conduit leading to a second outlet, the valve being susceptible to react to fluid density which surrounds it in order to be able to repress a first liquid towards the first outlet, a second liquid, of density more important, being driven back to the second exit by the second conduit.
  • the present invention has the advantage of using an installation, whose maintenance is infrequent, especially for the components installed in the well, and which can be done in a simple way from the exit of the well.
  • a well generally represented at 10, which, in the example illustrated, is an oil well, extends from the surface 12 of the ground, which can be the bottom of the sea, to a layer of reservoir rock 14.
  • Well 10 is provided with a casing 16, extending along the well, and with a production tubing 18 extending from surface 12 to a point below a seal 20, called "packer", mounted in the casing in a leaktight manner at a point located a few meters, or a few tens of meters, below of the reservoir rock 14.
  • a conduit 22, provided with a valve check valve 24, is arranged in a seal assembly 26, or packer, mounted in the well around the casing 18 at a point above the rock layer 14.
  • the casing 18 comprises, at a point located approximately 100 m from surface 12, a safety valve 27 disposed immediately above a second packer 28 advantageously mounted in the well.
  • the casing 18 AT its upper end, the casing 18 comprises an assembly of production valves 29, or "Christmas tree" intended for control the production rate of the well, and ensure its security. This set of valves communicates with a conduit production 30 forming the outlet of the well.
  • the casing 18 comprises, towards its lower end, a valve non-return 32 intended to allow the liquid to flow only towards exit 30.
  • a distribution system formed by example of a set 34 of control valves is connected to a low pressure gas source 36, and a gas source high pressure 38.
  • the pressure from each of the two sources of gas 36 and 38 is chosen according to the characteristics of the well, for example its depth, or the pressure of the deposit. As will be described in more detail below, these characteristics change over time, during the well production. Also, is it necessary to modify the gas pressures used correspondingly, in function of time.
  • the set of valves 34 communicates with the space annular 40, or chamber, defined between the casing 16 and the casing 18 and delimited by the packer 28 and the set of joint 26 by safety valves 42 and a conduit 44 which passes through a tubing suspension joint 46 or "tubing hanger" mounted at the upper end of the well.
  • a annular space safety valve 48 can be mounted at the end of conduit 44.
  • the seal assembly 26 is provided with a device allowing the re-injection of water, which, in the example illustrated, is a valve 52, shown in more detail in FIG. 1A.
  • This valve 52 comprises a tubular body 54, substantially coextensive with the casing 18 and provided with lateral openings 56, four in the illustrated example, which put the space annular 40 in communication with the lower end 58 tubing 18.
  • This lower end 58 is provided with a non-return valve 60 which allows the flow of fluid, coming from the annular space 40, in the direction of the arrow 62 towards an aquifer underlying reservoir 14, no represented.
  • the valve 52 includes a ball 64 which is adapted to abut on a seat 66 formed in the body 54, thereby closing the passage to the end lower 58 of the casing 18.
  • the density of the ball 64 is chosen to be superior to that of hydrocarbons liquids from reservoir rock 14, but lower to that of water. Located near 0.9, this density results in ball 64 floating in water, but, when in the presence of hydrocarbons, it descends on seat 66, thus closing the end lower 58 of the casing 18.
  • a conduit 50, on the whole seal 26, allows access to the valve 52 for possible maintenance operations.
  • the annular space 40 is put in communication, by the set of control valves 34, with the low pressure gas source 36.
  • the low pressure prevailing in the annular space 40 allows the mixture of hydrocarbons and water forming the effluent, coming from the reservoir layer 14, to go back up inside the well, through valve 24 and conduit 22, filling the annular space 40 to an intermediate level 67 upper, and thus driving the low pressure gas from the reservoir towards its source.
  • the installation is not equipped oil level sensors, this level intermediate is determined according to the characteristics tank, gas pressure and time. The weather necessary for the oil to reach its level stabilization is very long, we use a level intermediate, below the maximum possible level, that the hydrocarbons reach after a predetermined time.
  • the effluent from the reservoir rock 14 comprises a mixture of hydrocarbons and water.
  • the hydrocarbons separate from the water, which, being more dense, collects towards the lower end of the annular space 40.
  • the ball 64 of valve 52 being in the water, rises from its seat 66 and opens the passage from the annular space 40 to the aquifer, which however cannot fill the annular space due to valve 60.
  • An intermediate level is determined according to the back pressure on the discharge line, pressure of the gas, geometric characteristics of the well and time. Indeed, the time required for the hydrocarbons reach a level of stabilization, level which must be find above opening 68 to avoid a high pressure gas recirculation is again very long. Also, we use an intermediate level, above the minimum possible that the oil reaches after a predetermined time. Once this time is up, all of the valves 34 are actuated again and the space annular 40 is isolated from the high pressure gas source 38 and put in communication with the low pressure source 36. Thus, the gas pressure in the annular space 40 decreases quickly, allowing liquids from the tank to get back to filling this space 40. Then the cycle of the operation described above is repeated. Like pressure of the well changes over time, it is necessary to proceed to periodic measurements of the static pressure of the well in order to correspondingly modify the pressures of gas.
  • the number of wells, or well sets, will then be determined based on compared durations of the two phases, so as to optimize the overall production throughput.
  • Figure 2 is shown an installation for a oil well which, unlike that of Figure 1, does not have an underlying aquifer to which the water coming from the reservoir rock 14 can be driven back.
  • Figure 2 the elements common with those of the installation of figure 1 carry the same figures of reference.
  • This second casing 70 extends from the assembly of seal 26, through packer 28 and opens in a chamber 72 delimited between the packer 28 and the suspension seal 46 casing.
  • This room 72 communicates with a device common re-injection, or evacuation of water (not represented) by a conduit 74 provided with a safety valve 76. If the well is not equipped with a packer 28, the second casing 70 extends to the surface.
  • the method of implementing the installation of the figure 2 is substantially similar to that of the installation of the figure 1.
  • the pumping method and installation according to the invention may apply to subsea wells or wells earth, as well as vertical or inclined wells. He is at note that this device also allows separation at less partial of the gas dissolved in the effluent from the reservoir 14, the gas thus separated rising through the conduit 44, to the low pressure gas tank 36.
  • the physical separation between phases being carried out at the bottom, the discharge towards the surface could be achieved by a single conduit, the arrival of phases in sequence allowing their individualized treatment at the wellhead level, in order to send the phases towards their respective exits.
  • FIG. 3 differs from that of FIG. 1 in that the pumping installation is intended to pump the water separated from the hydrocarbons to the reservoir rock 14 instead of sending it to an aquifer like this. is the case in the installation of figure 1.
  • the elements already present in FIG. 1 bear the same reference numbers.
  • the end 58 of the casing 18 opens immediately below the seal assembly 26, in a chamber 80 defined in the lower end of the well 10.
  • the reservoir rock layer has a thickness more important than that of the embodiment of the Figure 1 and has a very high permeability.
  • the pumping process implemented using the installation of FIG. 3 is substantially similar to that of Figure 1.
  • water is towards the lower end of the annular space 40 and the valve 52 is open.
  • gas from the high pressure source 38 is sent to annular 40, the water is discharged by this gas through the valve 52 and the along the end 58 of the production casing 18 towards the room 80.
  • the water enters, in the direction of the arrows 84, in the lower part of the rock layer 14 by the lower perforations 82.
  • the water propagated in the rock layer 14 it tends to move, or expel the hydrocarbons present in the rock towards the chamber 80, then in the annular space 40.

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  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Jet Pumps And Other Pumps (AREA)
  • Lubrication Of Internal Combustion Engines (AREA)
  • Loading And Unloading Of Fuel Tanks Or Ships (AREA)
  • Lubricants (AREA)
  • Working-Up Tar And Pitch (AREA)
EP97401594A 1996-07-08 1997-07-04 Erdöl-Produktionseinrichtung und Verfahren Expired - Lifetime EP0818603B1 (de)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
FR9608478 1996-07-08
FR9608478A FR2750732B1 (fr) 1996-07-08 1996-07-08 Procede et installation de pompage d'un effluent petrolier

Publications (2)

Publication Number Publication Date
EP0818603A1 true EP0818603A1 (de) 1998-01-14
EP0818603B1 EP0818603B1 (de) 2002-10-02

Family

ID=9493808

Family Applications (1)

Application Number Title Priority Date Filing Date
EP97401594A Expired - Lifetime EP0818603B1 (de) 1996-07-08 1997-07-04 Erdöl-Produktionseinrichtung und Verfahren

Country Status (8)

Country Link
US (1) US5873410A (de)
EP (1) EP0818603B1 (de)
AT (1) ATE225459T1 (de)
CA (1) CA2209515C (de)
DE (1) DE69715981D1 (de)
FR (1) FR2750732B1 (de)
NO (1) NO312044B1 (de)
OA (1) OA10434A (de)

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NO313895B1 (no) * 2001-05-08 2002-12-16 Freyer Rune Anordning og fremgangsmÕte for begrensning av innströmning av formasjonsvann i en brönn
GB2396169B (en) * 2002-12-12 2005-03-16 Schlumberger Holdings Downhole separation of oil and water
US7290606B2 (en) 2004-07-30 2007-11-06 Baker Hughes Incorporated Inflow control device with passive shut-off feature
WO2006015277A1 (en) 2004-07-30 2006-02-09 Baker Hughes Incorporated Downhole inflow control device with shut-off feature
US7331397B1 (en) 2004-11-12 2008-02-19 Jet Lifting Systems, Ltd Gas drive fluid lifting system
US8096351B2 (en) * 2007-10-19 2012-01-17 Baker Hughes Incorporated Water sensing adaptable in-flow control device and method of use
US8312931B2 (en) * 2007-10-12 2012-11-20 Baker Hughes Incorporated Flow restriction device
US20090301726A1 (en) * 2007-10-12 2009-12-10 Baker Hughes Incorporated Apparatus and Method for Controlling Water In-Flow Into Wellbores
US7942206B2 (en) * 2007-10-12 2011-05-17 Baker Hughes Incorporated In-flow control device utilizing a water sensitive media
US7775277B2 (en) * 2007-10-19 2010-08-17 Baker Hughes Incorporated Device and system for well completion and control and method for completing and controlling a well
US7775271B2 (en) 2007-10-19 2010-08-17 Baker Hughes Incorporated Device and system for well completion and control and method for completing and controlling a well
US20090101329A1 (en) * 2007-10-19 2009-04-23 Baker Hughes Incorporated Water Sensing Adaptable Inflow Control Device Using a Powered System
US7784543B2 (en) * 2007-10-19 2010-08-31 Baker Hughes Incorporated Device and system for well completion and control and method for completing and controlling a well
US7918272B2 (en) * 2007-10-19 2011-04-05 Baker Hughes Incorporated Permeable medium flow control devices for use in hydrocarbon production
US7913755B2 (en) 2007-10-19 2011-03-29 Baker Hughes Incorporated Device and system for well completion and control and method for completing and controlling a well
US7913765B2 (en) * 2007-10-19 2011-03-29 Baker Hughes Incorporated Water absorbing or dissolving materials used as an in-flow control device and method of use
US7891430B2 (en) 2007-10-19 2011-02-22 Baker Hughes Incorporated Water control device using electromagnetics
US7789139B2 (en) 2007-10-19 2010-09-07 Baker Hughes Incorporated Device and system for well completion and control and method for completing and controlling a well
US7793714B2 (en) 2007-10-19 2010-09-14 Baker Hughes Incorporated Device and system for well completion and control and method for completing and controlling a well
US8069921B2 (en) 2007-10-19 2011-12-06 Baker Hughes Incorporated Adjustable flow control devices for use in hydrocarbon production
US8544548B2 (en) * 2007-10-19 2013-10-01 Baker Hughes Incorporated Water dissolvable materials for activating inflow control devices that control flow of subsurface fluids
US7918275B2 (en) 2007-11-27 2011-04-05 Baker Hughes Incorporated Water sensitive adaptive inflow control using couette flow to actuate a valve
US7597150B2 (en) * 2008-02-01 2009-10-06 Baker Hughes Incorporated Water sensitive adaptive inflow control using cavitations to actuate a valve
US8839849B2 (en) * 2008-03-18 2014-09-23 Baker Hughes Incorporated Water sensitive variable counterweight device driven by osmosis
US7992637B2 (en) * 2008-04-02 2011-08-09 Baker Hughes Incorporated Reverse flow in-flow control device
US8931570B2 (en) * 2008-05-08 2015-01-13 Baker Hughes Incorporated Reactive in-flow control device for subterranean wellbores
US8171999B2 (en) * 2008-05-13 2012-05-08 Baker Huges Incorporated Downhole flow control device and method
US7789152B2 (en) 2008-05-13 2010-09-07 Baker Hughes Incorporated Plug protection system and method
US8555958B2 (en) * 2008-05-13 2013-10-15 Baker Hughes Incorporated Pipeless steam assisted gravity drainage system and method
US8113292B2 (en) 2008-05-13 2012-02-14 Baker Hughes Incorporated Strokable liner hanger and method
US7762341B2 (en) * 2008-05-13 2010-07-27 Baker Hughes Incorporated Flow control device utilizing a reactive media
US20100300674A1 (en) * 2009-06-02 2010-12-02 Baker Hughes Incorporated Permeability flow balancing within integral screen joints
US20100300675A1 (en) * 2009-06-02 2010-12-02 Baker Hughes Incorporated Permeability flow balancing within integral screen joints
US8056627B2 (en) * 2009-06-02 2011-11-15 Baker Hughes Incorporated Permeability flow balancing within integral screen joints and method
US8132624B2 (en) * 2009-06-02 2012-03-13 Baker Hughes Incorporated Permeability flow balancing within integral screen joints and method
US8151881B2 (en) * 2009-06-02 2012-04-10 Baker Hughes Incorporated Permeability flow balancing within integral screen joints
US8893809B2 (en) * 2009-07-02 2014-11-25 Baker Hughes Incorporated Flow control device with one or more retrievable elements and related methods
US8550166B2 (en) * 2009-07-21 2013-10-08 Baker Hughes Incorporated Self-adjusting in-flow control device
US9016371B2 (en) * 2009-09-04 2015-04-28 Baker Hughes Incorporated Flow rate dependent flow control device and methods for using same in a wellbore

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US2986215A (en) * 1958-09-23 1961-05-30 Shell Oil Co Salt water disposal system
US4497714A (en) * 1981-03-06 1985-02-05 Stant Inc. Fuel-water separator
US4766957A (en) * 1987-07-28 1988-08-30 Mcintyre Jack W Method and apparatus for removing excess water from subterranean wells
US5161956A (en) * 1990-05-11 1992-11-10 Isco, Inc. Valve pump

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US4390061A (en) * 1980-12-31 1983-06-28 Charles Short Apparatus for production of liquid from wells
US4384962A (en) * 1981-03-06 1983-05-24 Stant Inc. Fuel-water separator
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US4791985A (en) * 1987-09-11 1988-12-20 Lagoven, S.A. System to proportion assisting fluids in a well
US5183391A (en) * 1990-05-11 1993-02-02 Isco, Inc. Valve pump
US5238060A (en) * 1992-09-08 1993-08-24 Oed Environmental Systems, Inc. Sampling pump with packer

Patent Citations (5)

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Publication number Priority date Publication date Assignee Title
US1499589A (en) * 1923-08-27 1924-07-01 Navin Frank Method and apparatus for extracting oil from wells
US2986215A (en) * 1958-09-23 1961-05-30 Shell Oil Co Salt water disposal system
US4497714A (en) * 1981-03-06 1985-02-05 Stant Inc. Fuel-water separator
US4766957A (en) * 1987-07-28 1988-08-30 Mcintyre Jack W Method and apparatus for removing excess water from subterranean wells
US5161956A (en) * 1990-05-11 1992-11-10 Isco, Inc. Valve pump

Also Published As

Publication number Publication date
CA2209515C (fr) 2005-10-25
NO973141D0 (no) 1997-07-07
EP0818603B1 (de) 2002-10-02
FR2750732B1 (fr) 1998-10-30
DE69715981D1 (de) 2002-11-07
ATE225459T1 (de) 2002-10-15
US5873410A (en) 1999-02-23
NO973141L (no) 1998-01-09
CA2209515A1 (fr) 1998-01-08
NO312044B1 (no) 2002-03-04
FR2750732A1 (fr) 1998-01-09
OA10434A (fr) 2001-12-07

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