WO1999002819A1 - Puits d'injection commandes par ordinateur - Google Patents

Puits d'injection commandes par ordinateur Download PDF

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Publication number
WO1999002819A1
WO1999002819A1 PCT/US1998/014230 US9814230W WO9902819A1 WO 1999002819 A1 WO1999002819 A1 WO 1999002819A1 US 9814230 W US9814230 W US 9814230W WO 9902819 A1 WO9902819 A1 WO 9902819A1
Authority
WO
WIPO (PCT)
Prior art keywords
injection
fluid
zone
production
sensor
Prior art date
Application number
PCT/US1998/014230
Other languages
English (en)
Inventor
Terry R. Bussear
Kevin R. Jones
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 AU84798/98A priority Critical patent/AU749714B2/en
Priority to GB0000475A priority patent/GB2343695B/en
Priority to CA002296054A priority patent/CA2296054C/fr
Publication of WO1999002819A1 publication Critical patent/WO1999002819A1/fr
Priority to NO20000113A priority patent/NO20000113L/no

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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
    • 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
    • E21B49/006—Measuring wall stresses in the borehole
    • 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
    • E21B37/00—Methods or apparatus for cleaning boreholes or wells
    • E21B37/06—Methods or apparatus for cleaning boreholes or wells using chemical means for preventing, limiting or eliminating the deposition of paraffins or like substances
    • 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
    • E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
    • E21B41/0035—Apparatus or methods for multilateral well technology, e.g. for the completion of or workover on wells with one or more lateral branches
    • 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
    • E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
    • E21B41/02—Equipment or details not covered by groups E21B15/00 - E21B40/00 in situ inhibition of corrosion in boreholes or wells
    • 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
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • 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
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/20—Displacing by water
    • 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
    • E21B47/00—Survey of boreholes or wells
    • E21B47/01—Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
    • E21B47/017—Protecting measuring instruments
    • 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
    • E21B47/00—Survey of boreholes or wells
    • E21B47/06—Measuring temperature or pressure
    • 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
    • E21B47/00—Survey of boreholes or wells
    • E21B47/06—Measuring temperature or pressure
    • E21B47/07—Temperature
    • 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
    • E21B47/00—Survey of boreholes or wells
    • E21B47/10—Locating fluid leaks, intrusions or movements
    • E21B47/107—Locating fluid leaks, intrusions or movements using acoustic means
    • 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
    • E21B47/00—Survey of boreholes or wells
    • E21B47/10—Locating fluid leaks, intrusions or movements
    • E21B47/113—Locating fluid leaks, intrusions or movements using electrical indications; using light radiations
    • 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
    • E21B47/00—Survey of boreholes or wells
    • E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
    • E21B47/13—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. radio frequency
    • E21B47/135—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. radio frequency using light waves, e.g. infrared or ultraviolet waves
    • 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
    • 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
    • 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
    • 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
    • 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
    • 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
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01D—MEASURING NOT SPECIALLY ADAPTED FOR A SPECIFIC VARIABLE; ARRANGEMENTS FOR MEASURING TWO OR MORE VARIABLES NOT COVERED IN A SINGLE OTHER SUBCLASS; TARIFF METERING APPARATUS; MEASURING OR TESTING NOT OTHERWISE PROVIDED FOR
    • G01D5/00—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable
    • G01D5/26—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light
    • G01D5/268—Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable characterised by optical transfer means, i.e. using infrared, visible, or ultraviolet light using optical fibres
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/40—Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V11/00—Prospecting or detecting by methods combining techniques covered by two or more of main groups G01V1/00 - G01V9/00
    • G01V11/002—Details, e.g. power supply systems for logging instruments, transmitting or recording data, specially adapted for well logging, also if the prospecting method is irrelevant
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V8/00—Prospecting or detecting by optical means
    • G01V8/02—Prospecting

Definitions

  • the invention is related to enhanced oil production. More particularly, the invention relates to a method and apparatus for controlling injection wells to optimize production from associated production wells.
  • Injection wells have, of course, been employed for many years in order to flush residual oil in a formation toward a production well and increase yield from the area.
  • a common injection scenario is to pump steam down an injection well and into the formation which functions both to heat the oil in the formation and force its movement through the practice of steam flooding. In some cases, heating is not necessary as the residual oil is in a flowable form, however in some situations the oil is in such a viscous form that it requires heating in order to flow.
  • steam one accomplishes both objectives of the injection well: 1) to force residual oil toward the production well and 2) to heat any highly viscous oil deposits in order mobilize such oil to flow ahead of the flood front toward the production well.
  • Breakthrough occurs when a portion of the flood front reaches the production well. As happens the flood water remaining in the reservoir will generally tend to travel the path of least resistance and will follow the breakthrough channel to the production well. At this point, movement of the viscous oil ends. Precisely when and where the breakthrough will occur depends upon water/oil mobility ratio, the lithology, the porosity and permeability of the formation as well as the depth thereof. Moreover, other geologic conditions such as faults and unconformities also affect the in-situ sweep efficiency.
  • the above-discussed and other drawbacks and deficiencies of the prior art are overcome or alleviated by the electronically controlled injection well system of the invention.
  • the invention provides significantly more information to well operators thus enhancing oil recovery to a degree not heretofore known. This is accomplished by providing real time information about the formation itself and the flood front as well as the produced fluid by providing permanent downhole sensors capable of sensing changes in the swept and unswept formation and/or the progression of the flood front and/or changes in the produced fluid (e.g. temperature). Preferably, a plurality of sensors would be employed to provide information about discrete portions of strata surrounding the injection well. This provides a more detailed data set regarding the well(s) and surrounding conditions.
  • the sensors are, preferably, connected to a processor either downhole or at the surface for processing of information. Moreover, in a preferred embodiment the sensors are connected to computer processors which are also connected to sensors in a production well (which are similar to those disclosed in U.S. Patent No. 5,597,042 which is fully incorporated herein by reference) to allow the production well to "talk" directly to the related injection well(s) to provide an extremely efficient real time automatic operation. Sensors employed will be to sense temperature, pressure, flow rate, electrical and acoustic conductivity, density, strain and to detect various light transmission and reflection phenomena. All of these sensor types are available commercially in various ranges and sensitivities which are selectable by one of ordinary skill in the art depending upon particular conditions known to exist in a particular well operation.
  • Specific pressure measurements will also include pressure(s) at the exit valve(s) down the injection well or injection zone in a single well and at the pump which may be located downhole or at the surface. Measuring said pressure at key locations such as at the outlet, upstream of the valve(s) near the pump, etc., will provide information about the speed, volume, direction, etc. at/in which the waterflood front (or other fluid) is moving. Large differences in the pressure from higher to lower over a short period of time could indicate a breakthrough. Conversely, pressure from lower to higher over short periods of time could indicate that the flood front had hit a barrier. Similarly, a rapid temperature rise in the produced fluid in one zone of the production well can indicate imminent breakthrough.
  • the present invention uses fluid densities to monitor the flood front from the trailing end.
  • the interface between the flood front and the hydrocarbon fluid provides an acoustic barrier upon which a signal can be bounced.
  • the profile of the front is generated in 4D i.e., three dimensions over time.
  • FIGURE 1 is a schematic representation of an injection well illustrating a plurality of sensors mounted therein;
  • FIGURE 2 is a schematic representation illustrating both an injection well and a production well having sensors and a flood front running between the wells;
  • FIGURE 3 is a schematic representation similar to FIGURE 2 but illustrating fluid loss through unintended fracturing; and FIGURE 4 is a schematic representation of an injection production well system where the wells are located on either side of a fault.
  • FIGURE 1 one of ordinary skill in the art will appreciate a schematic representation of an injection well 10. Also recognizable will be the representation of a flood front 20 which emanates from the injection well and is intended to progress toward a production well. This is additionally well represented in FIGURE 2 of the present application.
  • a plurality of sensors 12 are located permanently installed in the injection well and which are connected via the electrical wire cabling or fiber optic cabling to a processor which may either be a permanent downhole processor or a surface processor.
  • the system provides immediate real time information regarding the condition of the fluid front having been injected into the formation by the injection well or injection zone.
  • the sensors contemplated herein may be in the injection well or in both the injection well and the production well. They are employed in several different methods to obtain information such as that indicated above. Control is further heightened in the invention by providing a link between downhole sensors in the production well to the downhole sensors in the injection well as well as a connection to the flow control tools in both wells. By providing the operable connections to all of these parts of the system, the well can actually run itself and provide the most efficient oil recovery based upon the creation and maintenance of a uniform flood front.
  • the flood front can be regulated from both sides of FIGURE 2, i.e., the injection well and the production well, by opening production well valves in areas where the flood front is lagging while closing valves in areas where the flood front is advancing.
  • the fluid injection valves e.g., sliding or rotating sleeves, etc. would be choked or closed where the flood front is advancing quickly and opened more where the flood front is advancing slowly.
  • This seemingly complex set of circumstances is easily controlled by the system of the invention and rapidly remedies any abnormalities in the intended flood profile thus avoiding breakthrough of the injected fluid to the production well. Sweep efficiency of the steam or other fluid front is greatly enhanced by the system of the invention.
  • All of the sensors contemplated in the production well and the injection well are, preferably, permanently installed downhole sensors which are connected to processors and/to one another by electrical cabling or fiber optic cabling.
  • downhole sensors measure strain induced in the formation by the injected fluid.
  • Strain is an important parameter for avoiding exceeding the formation parting pressure or fracture pressure with the injected fluid.
  • This information is important in the regulation of pressure of the fluid to avoid such activity is that when pressure opens fractures or new fractures are created there is a path of much less resistance for the injected fluid to run through.
  • the injection fluid since the injection fluid will follow the path of least resistance, it would generally run in the fractures and around areas of the reservoir that need to be swept. Clearly, this substantially reduces the sweep efficiency of the injected fluid.
  • FIGURE 3 schematically illustrates the embodiment and the condition set forth above by illustrating an injection well 50 and a production well 60.
  • Fluid 52 is illustrated escaping via the unintended fracture from the formation 54 into the overlying gas cap level 56 and the underlying water table 61 and it is evident to one of ordinary skill in the art that the fluid is being lost in this location.
  • the condition is avoided by the invention by using pressure sensors to limit the injection fluid pressure as described above.
  • the rest of the fluid 52 is progressing as it is intended to through the formation 54.
  • acoustic sensors 56 are located in the injection well 50 at various points therein. Acoustic sensors which are well suited to the task to which they will be put in the present invention are commercially available from
  • the acoustic sensors pick up sounds generated by stress in the formation which propagate through the reservoir fluids or reservoir matrix to the injection well. In general, higher sound levels would indicate severe stress in the formation and should generate a reduction in pressure of the injected fluid whether by automatic control or by technician control.
  • a data acquisition system 58 is preferable to render the system extremely reliable and system 58 may be at the surface where it is illustrated in the schematic drawing or may be downhole. Based upon acoustic signals received, the system of the invention, preferably automatically (although manually is workable), reduces pressure of the injected fluid by reducing pump pressure. Maximum sweep efficiency is, thus, obtained.
  • acoustic generators and receivers are employed to determine whether a formation which is bifurcated by a fault is sealed along the fault or is permeable along the fault. It is known by one of ordinary skill in the art that different strata within a formation bifurcated by a fault may have some zones that flow and some zones that are sealed; this is the illustration of FIGURE 4.
  • injection well 70 employs a plurality of sensors 72 and acoustic generators 74 which, most preferably, alternate with increasing depth in the wellbore. In production well 80, a similar arrangement of sensors 72 and acoustic generators 74 are positioned.
  • the sensors and generators are preferably connected to processors which are either downhole or on the surface and preferably also connect to the associated production or injection well.
  • the sensors 72 can receive acoustic signals that are naturally generated in the formation, generated by virtue of the fluid flowing through the formation from the injection well and to the production well and also can receive signals which are generated by signal generators 74. Where signal generators 74 generate signals, the reflected signals that are received by sensors 72 over a period of time can indicate the distance and acoustic volume through which the acoustic signals have traveled. This is illustrated in area A of FIGURE 4 in that the fault line 75 is sealed between area A and area B on the figure. This is illustrated for purposes of clarity only by providing circles 76 along fault line 75.
  • the areas of fault line 75 which are permeable are indicated by hash marks 77 through fault line 75. Since the acoustic signal represented by arrows and semi-curves and indicated by numeral 78 cannot propagate through the area C of the drawing which bifurcates area A from area B on the left side of the drawing, that signal will bounce and it then can be picked up by sensor 72.
  • the time delay, number and intensity of reflections and mathematical interpretation which is common in the art provides an indication of the lack of pressure transmissivity between those two zones. Additionally this pressure transmissivity can be confirmed by the detection by said acoustic signals by sensors 72 in the production well 80.
  • area E is permeable to area B through fault 75 because the region D in that area is permeable and will allow flow of the flood front from the injection well 70 through fault line 75 to the production well 80.
  • Acoustic sensors and generators can be employed here as well since the acoustic signal will travel through the area D and, therefore, reflection intensity to the receivers 72 will decrease. Time delay will increase. Since the sensors and generators are connected to a central processing unit and to one another it is a simple operation to determine that the signal, in fact, traveled from one well to the other and indicates permeability throughout a particular zone.
  • the acoustic generators and sensors can provide the injection and production wells can run automatically by determining where fluids can flow and thus opening and closing valves at relevant locations on the injection well and production well in order to flush production fluid in a direction advantageous to run through a zone of permeability along the fault.
  • sensors 72 are clearly capable of receiving not only the generated acoustic signals but naturally occurring acoustic waveforms arising from both the flow of the injected fluids as the injection well and from those arising within the reservoirs in result of both fluid injection operations and simultaneous drainage of the reservoir in resulting production operations.
  • the preferred permanent deployment status of the sensors and generators of the invention permit and see to the measurements simultaneously with ongoing injection flooding and production operations. Advancements in both acoustic measurement capabilities and signal processing while operating the flooding of the reservoir represents a significant, technological advance in that the prior art requires cessation of the injection/ production operations in order to monitor acoustic parameters downhole.
  • the flood front is monitored from the "back" employing sensors installed in the injection well.
  • the sensors which are adequately illustrated in FIGURES 1 and 2 provide acoustic signals which reflect from the water/oil interface thus providing an accurate picture in a moment in time of the three-dimensional flood front. Taking pictures in 4-D i.e., three dimensions over real time provides an accurate format of the density profile of the formation due to the advancing flood front. Thus, a particular profile and the relative advancement of the front can be accurately determined by the density profile changes.
  • sensors and acoustic generators it is certainly possible to limit the sensors and acoustic generators to the injection well for such a system, however it is even more preferable to also introduce sensors and acoustic generators in the production well toward which the front is moving thus allowing an immediate double check of the fluid front profile. That is, acoustic generators on the production well will reflect a signal off the oil/water interface and will provide an equally accurate three-dimensional fluid front indicator. The indicators from both sides of the front should agree and thus provides an extremely reliable indication of location and profile.
  • the invention is also directed to a single wellbore having at least a production zone and an injection zone. This may occur in a single primary bore or may occur in a multilateral well where the injection zone is in one of the laterals and the production zone in another of the laterals.
  • An example of this latter type system is where a lateral and generally horizontal bore is above a formation and another is below the formation and where injected steam is employed to heat very viscous oil in the formation allowing it to gravity feed to the production zone thereunder.

Abstract

L'invention se rapporte à des procédés et à un dispositif destinés à réguler et contrôler les paramètres de la zone d'injection et de la zone de production de manière à réguler le front du fluide injecté et ce, dans le but d'empêcher la percée du fluide injecté dans la zone de production et ainsi d'optimiser la récupération d'hydrocarbures.
PCT/US1998/014230 1997-07-09 1998-07-09 Puits d'injection commandes par ordinateur WO1999002819A1 (fr)

Priority Applications (4)

Application Number Priority Date Filing Date Title
AU84798/98A AU749714B2 (en) 1997-07-09 1998-07-09 Computer controlled injection wells
GB0000475A GB2343695B (en) 1997-07-09 1998-07-09 Computer controlled injection wells
CA002296054A CA2296054C (fr) 1997-07-09 1998-07-09 Puits d'injection commandes par ordinateur
NO20000113A NO20000113L (no) 1997-07-09 2000-01-10 Datastyrte injeksjonsbrønner

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US5204297P 1997-07-09 1997-07-09
US60/052,042 1997-07-09

Publications (1)

Publication Number Publication Date
WO1999002819A1 true WO1999002819A1 (fr) 1999-01-21

Family

ID=21975064

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US1998/014230 WO1999002819A1 (fr) 1997-07-09 1998-07-09 Puits d'injection commandes par ordinateur

Country Status (5)

Country Link
AU (1) AU749714B2 (fr)
CA (1) CA2296054C (fr)
GB (1) GB2343695B (fr)
NO (1) NO20000113L (fr)
WO (1) WO1999002819A1 (fr)

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WO2001011189A3 (fr) * 1999-08-05 2001-11-15 Cidra Corp Appareil servant a optimiser la production d'un fluide polyphasique
FR2826449A1 (fr) * 2001-06-26 2002-12-27 Schlumberger Services Petrol Procede et installation de determination de la position du front forme a l'interface entre deux fluides contenus dans un reservoir
US6538576B1 (en) 1999-04-23 2003-03-25 Halliburton Energy Services, Inc. Self-contained downhole sensor and method of placing and interrogating same
WO2003040517A1 (fr) * 2001-11-05 2003-05-15 Weatherford/Lamb, Inc. Ensemble socle d'ancrage et ses procedes d'utilisation dans un forage
GB2398810A (en) * 2003-02-26 2004-09-01 Schlumberger Holdings Downhole fluid measuring system
WO2008152599A2 (fr) * 2007-06-12 2008-12-18 Schlumberger Canada Limited Interprétation en boucle fermée en temps réel de systèmes et de procédés de traitement de tuyauterie
WO2009009437A2 (fr) 2007-07-06 2009-01-15 Halliburton Energy Services, Inc. Détection de signaux acoustiques depuis un système de puits
CN103328762A (zh) * 2010-10-20 2013-09-25 卡姆肯石油有限公司 流体喷射装置
US8902078B2 (en) 2010-12-08 2014-12-02 Halliburton Energy Services, Inc. Systems and methods for well monitoring
WO2015073032A1 (fr) * 2013-11-15 2015-05-21 Landmark Graphics Corporation Optimisation de propriétés de dispositif de régulation du débit sur un puits de production dans des systèmes de noyage de puits d'injection et de production couplés
WO2015073031A1 (fr) * 2013-11-15 2015-05-21 Landmark Graphics Corporation Optimisation de propriétés de dispositif de commande d'écoulement pour injection de liquide accumulé
WO2018141841A3 (fr) * 2017-02-01 2019-10-17 Wfs Technologies Ltd Système de surveillance d'écoulement
RU2720848C1 (ru) * 2020-01-20 2020-05-13 Публичное акционерное общество "Татнефть" имени В.Д. Шашина Способ разработки нефтяной залежи с межпластовыми перетоками

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* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6415864B1 (en) * 2000-11-30 2002-07-09 Schlumberger Technology Corporation System and method for separately producing water and oil from a reservoir

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CN101796262A (zh) * 2007-07-06 2010-08-04 哈利伯顿能源服务公司 检测来自井系统的声音信号
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GB2537267B (en) * 2013-11-15 2020-11-04 Landmark Graphics Corp Optimizing flow control device properties on a producer well in coupled injector-producer liquid flooding systems
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GB2343695B (en) 2002-03-20
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GB0000475D0 (en) 2000-03-01
NO20000113L (no) 2000-03-08

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