WO2001049973A1 - Procede et dispositif d'essai de production de fond - Google Patents

Procede et dispositif d'essai de production de fond Download PDF

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Publication number
WO2001049973A1
WO2001049973A1 PCT/US2001/000328 US0100328W WO0149973A1 WO 2001049973 A1 WO2001049973 A1 WO 2001049973A1 US 0100328 W US0100328 W US 0100328W WO 0149973 A1 WO0149973 A1 WO 0149973A1
Authority
WO
WIPO (PCT)
Prior art keywords
fluid
production
zone
test string
formation
Prior art date
Application number
PCT/US2001/000328
Other languages
English (en)
Inventor
Rune Woie
Harald Grimmer
Original Assignee
Baker Hughes Incorporated
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 Baker Hughes Incorporated filed Critical Baker Hughes Incorporated
Priority to AU24742/01A priority Critical patent/AU2474201A/en
Publication of WO2001049973A1 publication Critical patent/WO2001049973A1/fr

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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
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
    • E21B49/08—Obtaining fluid samples or testing fluids, in boreholes or wells
    • E21B49/087—Well testing, e.g. testing for reservoir productivity or formation parameters
    • E21B49/088—Well testing, e.g. testing for reservoir productivity or formation parameters combined with sampling
    • 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
    • E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
    • E21B41/005—Waste disposal systems
    • E21B41/0057—Disposal of a fluid by injection into a subterranean formation
    • 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
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
    • E21B49/008—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by injection test; by analysing pressure variations in an injection or production test, e.g. for estimating the skin factor

Definitions

  • This invention relates generally to oilfield well testing and more particularly to production testing of wells wherein fluid from a production zone is injected into a another subsurface zone.
  • a production zone or zones are identified by a variety of known techniques. “Production test” or “production testing” is carried out to obtain data to determine a variety of characteristics of the oil and gas reservoirs, including the flow characteristics of the reservoir fluid, such as permeability.
  • Production tests are performed prior to completing a well (in open holes) as well as in cased or
  • a production test has two phases, each with a duration of several hours to a few days.
  • the fluid adjacent the production zone flows into the well, but gradually the fluid from greater distances must flow into the well.
  • the pressure in the well decreases because the fluid must flow over a longer distance through the formation, subjecting it to increasing pressure loss.
  • the pressure in the well depends only on the character of the formation.
  • pressure and temperature measurements over time are recorded, during constant flow rate.
  • the fluid flow from the production zone being tested is stopped.
  • the pressure within the well then gradually rises to the formation pressure as the formation around the well is filled with the fluid from the remote areas.
  • the pressure build up overtime and temperature overtime are recorded.
  • the pressure overtime, temperature overtime and the flow rate measurements are most commonly used to analyze the reservoir characteristics.
  • the reservoir fluid is conducted to the surface via a tubing.
  • Packers in the annulus between the tubing and the well are placed to seal the annulus so the formation fluid will flow through the tubing and not through the annulus.
  • a flow control valve at the upper end of the tubing at the surface is used to control the flow of the fluid from the formation.
  • Downhole pumps are sometimes installed to maintain the desired fluid flow rate.
  • casing is often cemented in the well to insulate various permeable layers, and to comply with safety requirements.
  • special production tubing is used down to the layer/bed (zone) to be tested.
  • These preparations are time-consuming and expensive.
  • Safety considerations make it sometimes necessary to strengthen an already set casing, perhaps over the entire or a substantial part of the length of the well; particularly in high pressure wells where it might be required to install extra casings in the upper parts of the well.
  • Such stimulation may include injection of chemicals into the formation in order to increase the flow rate.
  • a simple well stimulation includes subjecting the formation to pressure pulses so that it cracks and, thus, becomes more permeable. Such methods are referred to as "fracturing" of the formation.
  • a side-effect of fracturing can be a large increase in the amount of sand accompanying the reservoir fluid.
  • it may in some instances be of interest to be able to effect a well stimulation in order to observe the effect thereof. Again, the case is such that an ordinary production equipment is adapted to avoid, withstand, resist and separate out sand, while corresponding measures are of less importance when carrying out a production test.
  • Reversed production test may contribute to revealing a possible connection in the rock ground between formations connected by the channel, and may in some cases also contribute to defining the distance from the well to such a possible connection between the formations.
  • the present invention provides systems and methods for performing production testing in open holes and in cased holes that avoid transporting formation fluid to the surface.
  • a main feature of the invention is that formation fluid is conducted from a first, expected permeable formation to a second permeable formation as opposed to prior art technique where fluid is conducted between a formation and the surface.
  • at least one channel connection is established between two formations, of which one (a first) formation is the one to be production tested.
  • sealing devices are disposed to limit the fluid flow between the formations through the channel connection(s). When fluid flow takes place from the first to the second formation the sealing devices, e.g. annulus packers, prevent fluid from flowing between the formations, outside the channel(s).
  • flow controlling devices are disposed, which may include flow control valves and a pump, operable from the surface in order to control the fluid flow in the channel and, thus, between the formations.
  • a flow rate sensor is disposed within the channel. This sensor may be readable from a surface location.
  • sensors adapted to determine pressure, temperature, detect sand, water and the like from the surface may be disposed.
  • sensors for pressure and temperature are disposed within the well.
  • equipment for timekeeping and recording of the measured valves are positioned in the well.
  • Storing produced reservoir fluid in a formation results in the advantage that the fluid may have approximately reservoir conditions when it is conducted back into the reservoir.
  • well stimulating measures in the formation being production tested may be used. Fracturing may be achieved by methods known in the art. To this end, the well is supplied with pressurized liquid, e.g., through a drill string coupled to the channel. Thereafter, a production test is carried out as described above. Additionally, a reversed production test may be conducted to obtain the production testing data from two separated layers without having to remove the test string.
  • Figure 1 shows, diagrammatically and in a side elevational view, a part of a sketch of a well where a channel has been disposed which connects two permeable formations.
  • Figure 1A corresponds to Figure 1, but here is shown a minor modification of the channel-forming pipe establishing the fluid flow path between the two formations, the borehole through said second formation not being lined.
  • Figure 2 shows a part of a well having a channel, corresponding to Figure 1, and where a pump has been disposed.
  • Figure 3 shows a schematic elevational view of a cased well that has been prepared for production testing wherein formation fluid from a production zone is injected into an injection zone below the production zone.
  • Figure 4 shows a schematic elevational view of a cased well that has been prepared for production testing wherein formation fluid from a production zone is injected into a formation above the production zone.
  • Figure 5 shows a schematic elevation view of an open hole that has been prepared for production testing according to one method of the present invention.
  • Figure 6 shows a schematic elevation view of a wellbore with multiple production zones that has been prepared for production testing of one or more zones according to one method of the present invention.
  • reference numeral 1 denotes a part of a vertical well lined
  • the well 1 is extended with an open (not lined) hole 3 drilled
  • casing 2 is provided with a perforation 5 in an area where the well 1 passes
  • permeable formation 6 is not insulated or isolated by the casings 2.
  • permeable formations 4 and 6 may be stimulated using chemicals or may be fractured using a fracture mechanism (not separately shown) to increase flow in the formations 4 and 6.
  • a well known device and method of fracturing a formation is a pump used to initiate pressure pulses for causing cracks to form in the formation.
  • First formation 4 is insulated from possible permeable formations
  • the channel 8 is closed at the upper end and, according to Figures 1
  • the channel 8 below the place where the upper packer 11 is mounted, the channel 8 is provided with gates 13 establishing a fluid communication between the
  • the packer 7 can also be a part of the channel-
  • the annulus packer 7 When the annulus packer 7 is mounted to the channel-forming pipe 8, the latter may be closed at the lower end thereof which, according to Figure 1A, is positioned below the first, expected permeable formation layer 4. In an area above the annulus packer 7, the channel-forming pipe 8 is, thus, provided with through-going lateral gates 21 which, together with the through-going lateral gates 13, establish fluid communication between the formations 4 and 6.
  • a remotely operable valve (not shown) is disposed, said valve being adapted to control a fluid flow through the channel 8.
  • the valve may, as known per se, comprise a remotely operated displaceable, perforated sleeve 14 adapted to cover the gates 13, wholly or in part, the radially directed holes 14a of the sleeve 14 being brought to register more or less with the gates 13 or not to register therewith.
  • remotely readable sensors are disposed, inclusive a pressure sensor 15, and a flow sensor 16 and a temperature sensor 17.
  • the channel 8 may be assigned a pump 18 adapted to drive a flow of fluid through the channel 8.
  • the pump can be driven by a motor 19 placed in the extension of the channel 8.
  • a drive shaft 20 between motor 19 and pump 18 is passed pressure-tight through the upper closed end of the channel 8.
  • the motor 19 may be of a hydraulic type, adapted to be driven by a liquid, e.g. a drilling fluid which, as known, is supplied through a drill string or a coilable tubing, not shown.
  • an electrical motor can be used which can be cooled through the circulation of drilling liquid or through conducting fluid flowing in the channel 8, through a cooling jacket of the motor 19.
  • sensors may be disposed, in order to sense and point out communication or cross flowing to or from the permeable layers, above or below the annulus.
  • FIG. 3 shows schematic elevation view of a cased well 101 that has been prepared for production testing according to one embodiment of the present invention.
  • the well has been lined with a casing 103 that has perforations 105 adjacent a production zone or formation 106 to be tested and perforations 107 adjacent a permeable injection zone or formation 108.
  • the test string 110 generally includes a bottom hole assembly 100 conveyed in the well 101 with a drill pipe 112.
  • the bottom hole assembly 100 has a tubular member 115 that carries the various test devices.
  • the test string 110 includes a lower packer or seal 120a and an upper packer 120b that respectively seal the annulus 123 between the tubing 115 (also referred to herein as the tubular channel or the channel) and the casing 103.
  • packers 122a and 122b seal the annulus 125 between the tubing 115 and the casing 103 below and above the perforations 107 ensuring that the fluid from the tubing 115 will only be pumped
  • the string 110 includes a motor 130 that drives a pump 132 disposed at a suitable location in the tubing 115.
  • a drive shaft 131 coupled to the motor 130 passes through the packer or seal 120b and drives the pump 132. Seals 133 around the shaft 131 inhibit fluid communication through the packer 120b.
  • the motor 130 preferably is a mud motor which is driven when drilling fluid or mud 135 supplied to the drill pipe 112 under pressure from the surface.
  • the mud 135 drives the motor 130 and re-circulates or returns to the surface via the annulus 138 when a motor exit valve 137 is opened.
  • the motor 130 may also be an electric motor or any other type of suitable motor.
  • the motor may be a reversible type so that fluid may be pumped in either the uphole or downhole direction.
  • a stabilizer/centralizer 139 may be provided above the motor 130 to provide lateral or radial stabilization to the string 110.
  • the test string 110 further includes a shut-in valve 140 which controls the flow of the fluid from formation 106 to the tubing 115.
  • An injection valve 142 controls the fluid flow from the tubing 115 to the injection zone 108.
  • a circulation valve 144 at the bottom of the tubing 115 may be provided to control fluid flow from the tubing 115 to the wellbore section below the string 110.
  • a float valve 146 may be provided inside the rotor to prevent the back flow of the produced fluid 109.
  • a bypass valve 145 is provided in the packer 120b. During tripping of the string 110 into the well 101, the bypass valve 145 is opened, which allows the mud 135 to return to the surface via the annulus between the tubing 115 and
  • the string 110 includes a variety of sensors. Pressure sensors P ⁇ P 2 and P 3 respectively provide pressures in the tubing 115 adjacent the production zone 106, in the intermediate zone 110 and the injection zone 108. Temperature sensors T.,, T 2 and T 3 provide temperatures corresponding to the pressures P 1 , P 2 and P 3 .
  • Flow measurement devices such as "V" provides fluid flow rate through the tubing 115. Other flow meters may be used to measure flow rates and to detect leaks.
  • a fluid sampler 150 also referred to in the art as fluid collection chamber
  • the string 110 preferably includes a number of other sensors for determining reservoir characteristics. Such sensors include sensors for determining viscosity, density, bubble point, composition and other chemical characteristics of the formation fluid. The sensors are generally denoted by "RCI" in Figure 3. For motion evaluation, sensors such as resistivity sensors, acoustic and gamma ray sensors are disposed to provide parameters of interest of the formation. Such sensors may be conveniently placed above the motor 139.
  • Such sensors are designated a measurement-while-drilling or "MWD" sensors and are denoted by numeral 152.
  • a retrievable downhole memory unit 154 is preferably utilized to store the production testing data, which is downloaded at the surface for further analysis. The memory unit 154 can be retrieved by a wireline or coiled tubing if the string 110 gets stuck in the well.
  • the string 110 is conveyed into the wellbore.
  • the packers 120a and 120b, 122a and 122b are set at the preferred locations. The precise location of the zones may be determined from the MWD sensors 154.
  • the drilling fluid 135 is supplied under pressure, which rotates the motor that drives the pump 132.
  • the mud 135 returns or re-circulates to the surface via the motor exit valve 139.
  • the shut-in-valve 140 and the injection valves 142 are controllably opened to control the flow of the formation fluid from the production zone 106 to the injection zone 108.
  • the pressure, temperature and flow measurements are continuously or periodically recorded into the memory 154.
  • Electronic circuitry 153 preferably including microprocessor-based unit in the string 110 determines the values of various desired parameters from the downhole measurements. These measured values and data may be transmitted to a surface controller or processor which may be a computer system.
  • the downhole processor and/or the surface control unit are programmed to control the various flow control devices, and may be programmed to control the fluid flow rate from the production zone 106 to the injection zone 108.
  • shut- in-valve and the injection valve are turned off, and the fluid communication between the production and injection zone stopped.
  • the pressure in the zone 123 starts to rise.
  • the pressure over time and temperature over time measurements are recorded until the pressure P 1 builds up to the formation pressure or for a selected time period.
  • the production testing measurements may be recorded in downhole memory 154 and/or transmitted to a surface controller.
  • the valves 137, 140, 142, 145, and 146 and other such devices are remotely controllable.
  • the system can control the flow of fluid from the production zone 108 to the injection zone at any desired flow rate.
  • the system is a closed loop system, wherein the operating parameters may be altered downhole, from the surface, or any other remote location.
  • pressure and temperature measurements for the injection zone also may be recorded, which provides data for characterizing the injection zone during a single trip.
  • the fluid samples may be analyzed downhole by the reservoir characterization instruments ("RCI"). Fluid samples are collected by the sampler 150 and are analyzed upon retrieval of the string 110 to the surface.
  • Figure 4 is an example of the implementation of production testing in a cased well wherein the production zone 206 is below or downhole of the
  • the operation of the various valves is the same as described above.
  • the sampler 250 is disposed above the pump 232 since that is the high pressure side.
  • the packers 220a and 220b isolate the production zone 206 while the packers 222a and 222b isolate the injection zone 208.
  • the remaining elements are identified by the same numerals as shown in Figure 3.
  • Figure 5 shows an example of implementation of the production testing method of the present invention in an open hole 301.
  • the system 300 is substantially identical to the system described in reference to Figure 4, except that suitable open hole packers and stabilizers are utilized.
  • the open hole packers 320a and 320b isolate the production zone while packers 322a and 322b isolate the injection zone.
  • Formation evaluation measurements made by the MWD sensors 156 may be utilized to precisely position the string 300 in the wellbore.
  • Figure 6 which comprises Figures 6A and Figure 6B, shows an implementation of the present method for testing multiple zones.
  • Figure 6 shows three production zones 406, 408 and 410 and one injection zone 412.
  • Each of the production zones is isolated.
  • packers 420a and 420b isolate zone 406, packers 422a and 422b isolate zone 408 and packers 424a and 424b isolate zone 410.
  • Each production zone has a corresponding shut-in- valve.
  • Valves 416, 418 and 420 respectively control the flow from the production zones 406, 408 and 410 into the tubing 415.
  • a common motor 430 and pump 432 may be utilized to pump the fluid from any of the producing zones into the
  • shut-in-valves 418 and 420 are closed, while the valve 416 is opened. This only allows fluid from formation
  • the system of Figure 6 also allows for testing zones sequentially or simultaneously. For example, any two of the three zones or all of the three zones may be tested simultaneously.
  • the flow rate of each zone is independently controlled by the surface and/or downhole controller.
  • additional downhole instruments and sensors may easily be deployed.
  • one or more types of known fluid analysis devices may be disposed prior to the sample collection chamber (sampler) or they may be positioned at any other suitable location.
  • Such sensors may include acoustic sensors, near infrared sensors, density measurement devices, chemical analysis devices etc.
  • the system is adapted to control operations downhole and/or from the surface.
  • the system provides the production testing measurements, fluid sampling and in-situ fluid analysis.
  • Reservoir characterization instrumentation is disposed downhole to provide substantially real-time information.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Physics & Mathematics (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Chemical & Material Sciences (AREA)
  • Analytical Chemistry (AREA)
  • Investigation Of Foundation Soil And Reinforcement Of Foundation Soil By Compacting Or Drainage (AREA)

Abstract

L'invention concerne des systèmes et des procédés permettant de mettre en oeuvre des essais de production dans des trous découverts et dans des trous entubés, sans transport de fluide de formation à la surface. L'invention comprend principalement une colonne d'essai permettant de tester une zone (6) de production traversée par un puits (3). Cette colonne comprend en outre un élément (8) de communication fluidique permettant le passage d'un fluide, un dispositif (11, 12) d'étanchéité permettant d'isoler une zone (6) de production traversée par ce puits (3), afin de faire passer le fluide provenant de la zone (6) de production dans l'élément de communication fluidique, et un second dispositif (7, 10) d'étanchéité espacé du premier dispositif (11, 12) d'étanchéité, permettant d'isoler une seconde zone (4) d'injection traversée par le puits (3), une pompe (18) permettant le pompage du fluide entre ces zones, et des dispositifs (13, 14) de régulation du débit.
PCT/US2001/000328 2000-01-06 2001-01-05 Procede et dispositif d'essai de production de fond WO2001049973A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AU24742/01A AU2474201A (en) 2000-01-06 2001-01-05 Method and apparatus for downhole production testing

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US17477700P 2000-01-06 2000-01-06
US60/174,777 2000-01-06

Publications (1)

Publication Number Publication Date
WO2001049973A1 true WO2001049973A1 (fr) 2001-07-12

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Cited By (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6330913B1 (en) 1999-04-22 2001-12-18 Schlumberger Technology Corporation Method and apparatus for testing a well
US6347666B1 (en) 1999-04-22 2002-02-19 Schlumberger Technology Corporation Method and apparatus for continuously testing a well
US6357525B1 (en) 1999-04-22 2002-03-19 Schlumberger Technology Corporation Method and apparatus for testing a well
US6382315B1 (en) 1999-04-22 2002-05-07 Schlumberger Technology Corporation Method and apparatus for continuously testing a well
FR2827334A1 (fr) * 2001-07-16 2003-01-17 Hydro Equipements Procede d'analyse selectif d'un fluide dans un forage et dispositif pour sa mise en oeuvre
US6575242B2 (en) 1997-04-23 2003-06-10 Shore-Tec As Method and an apparatus for use in production tests, testing an expected permeable formation
WO2016014793A1 (fr) * 2014-07-23 2016-01-28 Saudi Arabian Oil Company Procédé et appareil pour isolation zonale et traitements sélectifs de formations souterraines
CN108979614A (zh) * 2017-06-05 2018-12-11 中国石油天然气股份有限公司 一种地面油水分离同井注采系统
WO2022094210A1 (fr) * 2020-10-29 2022-05-05 Saudi Arabian Oil Company Procédé et système pour injection d'eau de souterrain à souterrain
WO2023118580A1 (fr) * 2021-12-23 2023-06-29 Testall As Système intelligent d'essais de puits

Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0697500A2 (fr) * 1994-08-15 1996-02-21 Halliburton Company Méthode et dispositif pour l'évaluation de la pression de gisement
WO1998048146A1 (fr) * 1997-04-23 1998-10-29 Shore-Tec As Procede et dispositif utiles dans l'essai de production d'une formation permeable attendue
EP1041244A2 (fr) * 1999-03-31 2000-10-04 Halliburton Energy Services, Inc. Procédés pour l'essai en fond de puits de formations souterraines et appareil pour sa mise en oeuvre

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0697500A2 (fr) * 1994-08-15 1996-02-21 Halliburton Company Méthode et dispositif pour l'évaluation de la pression de gisement
WO1998048146A1 (fr) * 1997-04-23 1998-10-29 Shore-Tec As Procede et dispositif utiles dans l'essai de production d'une formation permeable attendue
EP1041244A2 (fr) * 1999-03-31 2000-10-04 Halliburton Energy Services, Inc. Procédés pour l'essai en fond de puits de formations souterraines et appareil pour sa mise en oeuvre

Cited By (14)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6575242B2 (en) 1997-04-23 2003-06-10 Shore-Tec As Method and an apparatus for use in production tests, testing an expected permeable formation
US6347666B1 (en) 1999-04-22 2002-02-19 Schlumberger Technology Corporation Method and apparatus for continuously testing a well
US6352110B1 (en) 1999-04-22 2002-03-05 Schlumberger Technology Corporation Method and apparatus for continuously testing a well
US6357525B1 (en) 1999-04-22 2002-03-19 Schlumberger Technology Corporation Method and apparatus for testing a well
US6382315B1 (en) 1999-04-22 2002-05-07 Schlumberger Technology Corporation Method and apparatus for continuously testing a well
US6457521B1 (en) 1999-04-22 2002-10-01 Schlumberger Technology Corporation Method and apparatus for continuously testing a well
US6330913B1 (en) 1999-04-22 2001-12-18 Schlumberger Technology Corporation Method and apparatus for testing a well
FR2827334A1 (fr) * 2001-07-16 2003-01-17 Hydro Equipements Procede d'analyse selectif d'un fluide dans un forage et dispositif pour sa mise en oeuvre
WO2016014793A1 (fr) * 2014-07-23 2016-01-28 Saudi Arabian Oil Company Procédé et appareil pour isolation zonale et traitements sélectifs de formations souterraines
US9719336B2 (en) 2014-07-23 2017-08-01 Saudi Arabian Oil Company Method and apparatus for zonal isolation and selective treatments of subterranean formations
CN108979614A (zh) * 2017-06-05 2018-12-11 中国石油天然气股份有限公司 一种地面油水分离同井注采系统
WO2022094210A1 (fr) * 2020-10-29 2022-05-05 Saudi Arabian Oil Company Procédé et système pour injection d'eau de souterrain à souterrain
US11414968B2 (en) 2020-10-29 2022-08-16 Saudi Arabian Oil Company Method and system for subsurface to subsurface water injection
WO2023118580A1 (fr) * 2021-12-23 2023-06-29 Testall As Système intelligent d'essais de puits

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