WO1998012417A1 - Dispositif et procede de surveillance - Google Patents

Dispositif et procede de surveillance Download PDF

Info

Publication number
WO1998012417A1
WO1998012417A1 PCT/GB1997/002497 GB9702497W WO9812417A1 WO 1998012417 A1 WO1998012417 A1 WO 1998012417A1 GB 9702497 W GB9702497 W GB 9702497W WO 9812417 A1 WO9812417 A1 WO 9812417A1
Authority
WO
WIPO (PCT)
Prior art keywords
pipe
sensor
reservoir
completion
resistivity
Prior art date
Application number
PCT/GB1997/002497
Other languages
English (en)
Inventor
George Albert Brown
Original Assignee
Bp Exploration Operating Company Limited
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 Company Limited filed Critical Bp Exploration Operating Company Limited
Priority to AU42156/97A priority Critical patent/AU4215697A/en
Publication of WO1998012417A1 publication Critical patent/WO1998012417A1/fr

Links

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
    • 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
    • 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
    • E21B47/00—Survey of boreholes or wells
    • 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
    • E21B47/00—Survey of boreholes or wells
    • E21B47/10—Locating fluid leaks, intrusions or movements

Definitions

  • the present invention relates to a monitoring device and method of monitoring, in particular for use in oil and/or gas wells
  • a monitoring device is now provided enabling measurement of one or more parameters on a continuous basis during production to provide information on the conditions down hole, e g m the reservoir
  • the present invention provides a reservoir completion pipe provided with at least one external sensor
  • the present invention also provides a pipe stnng comprising said completion pipe carrying the sensor and at least one section of completion tube attached to said pipe
  • the present invention also provides a method of determining a parameter in a reservoir, which comprises passing down a hole into a reservoir a sensor, and measuring said parameter characterized by passing a reservoir completion pipe provided with at least one sensor into the reservoir and measuring said parameter
  • a method of producing oil or gas from a subterranean reservoir via a well which comprises passing a plurality of
  • I sections of production and reservoir completion pipe down said well into said reservoir and withdrawing oil and/or gas therefrom characterized in that at least one section of reservoir completion pipe is provided with at least one external sensor, said section of pipe is passed into the well into the reservoir, and during withdrawal of oil and/or gas the sensor measures one or more reservoir parameters
  • the reservoir completion pipe which is provided with the sensor may have any convenient internal and external diameter e.g. 2-10 inch ( 5 08-25.4cm) especially 4'/2, 7 or 9 ⁇ / inch (1 1.43, 17.78 or 24.45cm)
  • it has the same diameter, in particular internal diameter as the sections of completion pipe to which it is attached, so the sensor-carrying-pipe constitutes no restriction to fluid flow
  • It is usually made of steel and is of circular internal cross section It may be about the same length as a usual section of completion pipe e g about 10m, but advantageously is 0 5-5m long
  • one or both threaded ends may carry an electrically insulating coating, e g one sprayed onto the threads; the coating may be of thermoplastics material but preferably is of thermoset resin, and may be a silicone polymer Alternatively if desired the production pipe carrying
  • the sensor may be any conventional sensor and may measure temperature, pressure, fluid velocity, resistivity, density or relative proportions of produced fluids
  • suitable sensors include an external or internal pressure sensor or temperature sensor, an internal ultrasonic sensor, a low energy density sensor, a venturi flowmeter, or an external resistivity electrode
  • Suitable pressure sensors include quartz or strain gauge type sensors
  • a suitable external resistivity electrode may be of the multi-electrode type
  • the sensor may be mounted externally of the reservoir completion pipe It may simply be strapped onto the outside, but preferably is at least partly protected from damage within the external surface of the reservoir completion pipe or within a framework itself externally mounted on the pipe
  • the sensor may be in a slot or groove, which may be radial, circumferential or longitudinally extending
  • the slot or groove may be in the external wall of the pipe, which wall may otherwise of substantially uniform thickness.
  • the wall has at least one portion thicker than other portions, the thicker portion having in its external surface at least one groove or slot to receive the sensor or sensors; preferably the pipe has in transverse cross section, a pair of parallel outwardly extending external surfaces with a face to the pipe between them substantially normal to those surfaces.
  • the pipe may have one or more longitudinally extending grooves to receive the sensor or sensors.
  • the sensor or sensors may also be in an open elongate framework extending outwards at least one location from the pipe, which framework may be integral with or releasably attached to the pipe. Inside the framework is located the sensor or sensors.
  • the framework may be sufficiently open to allow radial access of the reservoir fluid to the sensor if required but may be sufficiently closed to restrict movement of, especially outward movement of, the sensor away from the pipe.
  • the framework may thus be partly open on its outside distant from the pipe, or may be closed on that outside, though in both cases it is open from its ends to allow access of fluid to the sensor.
  • the sensor(s) may also be in a housing mounted externally on the pipe, either releasably or preferably non- releasably e.g. by welding.
  • the housing may have the sensor outwardly facing and contain the associated electronic mechanisms.
  • the housing may be in the form of a sheath at least partly surrounding the pipe.
  • the sheath may surround the pipe and be in continuous contact therewith but preferably is in contact at its ends but not internally so the sheath and pipe define a cavity for the cable and sensor terminals (see later)
  • the sensors may be disposed symmetrically or asymmetrically in or around the periphery of the completion pipe.
  • the external sensor(s) is used to determine at least one parameter outside the pipe i e. in the formation while any internal sensor(s) is used to determine at least one parameter inside the pipe i.e of the pipe contents.
  • One or both types of sensor is preferably located in the pipe wall with external access e.g.
  • closure means e.g. a cap or screw threaded lid or grub screw; depending on the nature of the sensor, the closure means may be perforated to allow liquid access to the sensor but still protect it e g for a pressure sensor
  • the sensor will be located on/in the inside surface of the pipe wall
  • the wall may be of substantially uniform thickness in an axial direction, which thickness may be higher than that of the pipes to which it is attached, though preferably with the same internal diameter.
  • the sensor(s) is preferably in a chamber in the pipe wall accessible externally of the pipe.
  • the external form of the sensor may be a pod for insertion into the framework or an elongate body for insertion into the slot or groove.
  • the sensor is usually sealed apart from its measuring head, except as required e.g. for measuring temperature.
  • the completion pipe is provided with at least one sensor e.g. as described above, and especially a resistivity sensor either alone or with at least one other sensor; there may be at least 2 different sensors, especially when one sensor is a temperature sensor. Preferably there are 2-6 sensors, especially a resistivity sensor, and one or both of a temperature and pressure sensor.
  • the pipe is provided with more than one sensor, at least one, preferably the resistivity sensor is external of the pipe and the rest may be internal or external of the pipe, but especially with an internal and/or external pressure and/or temperature sensor and/or sensor for measuring flow and/or the relative proportions of the production fluids.
  • the overall completion pipe string through the reservoir has more than one sections of pipe provided with at least one sensor
  • the or each such section is provided with means for longitudinal aligning of the locations of the sensors on the pipe.
  • the sensors are all in the same side of the pipe string aiding their protection from damage and also minimising the length of cables, used to transmit measurement data from the sensors up the pipe string outside e.g. to the well head.
  • the sensor(s) transmits signals carrying the data to a data collecting means and hence data analysis system.
  • the mode of transmission may be down elongate signal transmission means, such as a wire or optical fibre lines or via radio or other waves. Such lines may pass in at least one passage in the pipe wall or in the external wall surface, as in a circumferential slot.
  • the data collecting means is usually at the surface.
  • a signal transmission line passes from each sensor to a junction box for the sensor-carrying-completion pipe, and the junction boxes from different completion pipes are joined together e.g. by armoured cable.
  • the cable preferably carries a return line for signals from more than one sensor of a particular type especially from all the sensors of that type; less preferred the cable may have one line for signals from each sensor
  • the cable also contains at least one line for powering one or more sensors, and the power line passes from each junction box to each sensor.
  • the junction box is usually mounted externally of the sensor-carrying-completion pipe, e.g. strapped on the outside but preferably in an axial groove in the pipe wall e.g. an external groove in at least one portion of the pipe wall, which may or may not be the same as any such portion in which the sensor may be located; the groove may extend substantially the full length of the sensor-carrying completion pipe with the junction box and the two cables received in it.
  • the pipe provided with the sensor is attached to a section of reservoir completion pipe, e.g. via their threaded portions
  • the sensor pipes may be separated by 1 or more sections of reservoir completion pipe e.g. may be between each alternate liner section and hence may be at about 10m or more intervals.
  • the reservoir completion pipe may already be perforated as in slotted liner pipe optionally wire wrapped, but is usually perforatable.
  • the devices of the invention may be installed and used as follows
  • the well is drilled into the reservoir underground and then in the completion step, completion pipe is passed downhole.
  • the pipe provided with the sensor, at a location in the pipe string commensurate with its location in the desired place in the reservoir
  • Cable e g armoured cable to transmit data from the sensor along appropriate lines e g wire or fibre optic lines is then attached to the sensor and fed downhole with one or more later sections of completion pipe attached to the sensor carrying pipe, further sensor pipe is added as required and the sensors joined up with cable
  • the rest of the completion and then production string is then attached and run downhole, and then well head completed
  • the sensor pipe is insulated from neighbouring pipe and electrical connections arc made to the sensor pipe and neighbouring pipe
  • the reservoir completion pipe is then perforated and oil/gas production started.
  • parameters such as water content can be determined, and in response to the data, the recovery process can be altered if required to optimise production
  • the devices of the invention may be used to provide information of flow in the well, as well as flows near the well and between neighbouring wells e g via resistivity measurements, and can replace use of many separate periodic reservoir surveillance logging operations, particularly under the sea (e.g. in subsea completed wells) where such operations are difficult and expensive.
  • the devices may also be used at different levels in the reservoir, whereas present devices give measurement at only one depth, above the reservoir and in the last cemented casing section of the well. Resistivity of the fluid cannot be determined in the latter case, whereas this can be easily performed with the devices of the invention.
  • the devices of the invention with a resistivity sensor can be used to measure resistivity in the near well bore region (up to lm from the bore), and would be an improvement on pulsed neutron and carbon oxygen existing equipment in low salinity and low porosity environments.
  • well resistivity tomography could be used to monitor the movement of flood fronts across the reservoir.
  • Surface electrodes in combination with the resistivity devices of the invention can be used to map the resistivity and thus saturation changes across a reservoir.
  • the completion pipe is effectively transformed into an array of resistivity electrodes by the insertion between 2 or more standard sections of the completion pipe (each about 10 metres long) of insulated sections or joints, usually short joints, of completion pipe of the invention (which also carry an resistivity electrode and can also carry other sensors) thus effectively insulating each joint of the completion pipe from its neighbours.
  • Each section or joint of pipe (both the sensor carrying insulated joints and the conventional 10m section) is individually connected to the surface [as exemplifying the data collection point] and each constitutes one electrode of an array of resistivity electrodes, for use in combination with one or more other resistivity electrodes, which may be on the surface of the formation [e.g.
  • the neighbouring pipe in question may be one joined directly to the pipe carrying the sensor or acting as the resistivity electrode, or may be spaced therefrom by one or more sections of completion pipe and/or pipes carrying sensors.
  • the other resistivity electrode may be another resistivity electrode in the same pipe string, with electrical connection to the surface.
  • the other resistivity electrode or electrodes may be on a neighbouring well, and may be a completion pipe or a pipe carrying a resistivity electrode again supplied with connection to the surface. Voltages can be applied across any combination of the resistivity electrodes in pairs, trios (e.g.
  • the completion pipes above and below the resistivity electrode at that depth can be charged separately as guard electrodes to a voltage similar to that to which the measure electrode is charged, this has the effect of focusing the movement of the current [and hence the resistivity measurement] at the depth required
  • Devices of the invention with a pressure sensor can be used to provide in real time information on fluid pressure gradients of the formation, e g identification of pressure boundaries and zones at different reservoir pressure in deviated (e g substantially horizontal) wells and vertical wells in layered reservoirs with cemented casings
  • identification and monitoring of oil/water and gas/oil contacts from the gradient lines when the well was shut in are possible as is identification of gas saturation in draining gas caps, by using the pressure gradient in conjunction with near well pressure analysis
  • These pressure sensors could replace individually run cased hole neutron logs, saturation monitoring tools and borehole density (gradiomanometer) tools
  • Devices with ultrasonic sensors can measure fluid velocity and relative proportions of produced fluids to determine water production
  • An array of several of such sensors on pipes along the reservoir length enables individual fluid velocities to be measured and fluid interface (and thus relative proportions of produced fluids) to be monitored in oil/water mixtures containing up to about 30% gas (by volume)
  • These devices would replace separate running of phase velocity, oxygen activation and spinner logs inside the casing
  • Figs 1 and 3 represent cross sections of two sensor pipes of the invention and Fig 2 represents a cross section of cemented casing above a reservoir, with the sensor pipes of the invention and completion pipes in the reservoir
  • pipe 1 is in the form of a stub joint usually 1 -7ft (0 3-2 13m) or 0 5-2m long It has threaded connection ends 2 and 3, being internally and externally threaded respectively, for engagement with corresponding threads on adjacent completion pipe
  • a sensor package 4 in the form of a sheath or housing is located around the outside of the pipe 1 about its middle and is welded thereto
  • On the outer surface of the package 4 is a circumferential slot 5 in which a resistivity sensor 6 is located.
  • Fig 2 the last section of casing 20 is cemented in place and has a production tubing 21 extending coaxially through it and separated from it by packers 22
  • Production tubing 21 has cabling 30 strapped on its outside Coaxially surrounding the tube 21 and extending downwardly beyond it is a reservoir completion pipe 23, which is supported via liner hanger 24 by casing 20
  • Reservoir completion pipe 23 is in electrical contact with cable 30 on production tubing 21 via wet connect/inductive couplings 25, which are in electrical contact with cable 15 extending down the outside of pipe 23 but insulated therefrom
  • Reservoir completion pipe 23 is interrupted by several sensor pipes 1 spaced along its length, the pipes having packages 4 joined to the cable 15 In several places down the length of reservoir completion pipe 23 and preferably all on the same side of the pipe 23 distant from the cable 15 are perforations 26
  • reservoir completion pipe 23 is run down hole with perforatable sections, and spaced down its length are sensor pipes 1 Each sensor pipe 1 is attached by the insulating threads 3 and 4 to the section of pipe 23 below and above it (respectively) Each pipe 1 is carefully aligned so the cable 15 is in the same location as in lower pipes 1 Cable 15 is then strapped to the pipe 1 (not shown) and then to the section(s) of reservoir completion pipe 23, above it Then a further sensor pipe 1 is threaded onto pipe 23 and the leads from the sensors fed into the cable 15 Cable 15 is then strapped to that pipe 1 (not shown) and then to the section(s) of pipe 23 above it etc The cable 15 is stopped on the section of reservoir completion pipe 23 which will be located just below the cemented casing 20.
  • the electrical circuits for the sensors are tested to ensure continuity and operation from cabling 30, coupling 25, cable 15 and the sensors in the packages 4
  • the reservoir completion pipe 23 is then perforated with a perforating gun (not shown) and then production started Continuously or continually the output from the sensors is monitored to provide information on the conditions in different parts of the reservoir, and appropriate action if any taken
  • Resistivity electrode sensor 6 usually has a wire connecting it electrically to the surface and a voltage is applied between it and a corresponding wire connected to the neighbouring completion pipe (not shown) from which pipe 1 is insulated bv coating 14 The voltage and current obtained provides a measure of the resistivity of the formation around the pipe 1 between sensor 6 and the neighbouring pipe (not shown)
  • pipe 1 is as in Fig 1 with connection ends 2 and 3, having insulated layers 14 as in Fig 1 Instead of package 4, the pipe 1 has a central outwardly extending wall portion 31 of greater thickness than the wall thickness nearer the ends 2 and 3
  • this portion 31 is a circumferential slot with resistivity sensor 6
  • Two external pressure sensors 7 are in portion 3 1 in radial slots 8 which are spaced by slot 5
  • Slots 8 and chamber 30 are in communication with grooves 32 and 33 respectively which extend circumferentially round wall portion 31 and contain wires or fibres (not shown) leading from sensoi s 7 and respectively to a junction box 34.
  • An internal pressure sensor 11 is in passage 12 extending outwardly from the inside of pipe 1, but closed by wall portion 31.
  • An internal flow sensor 1 as in Fig.1.
  • Junction box 34 is received in a longitudinal valley in wall portion 31 and houses the end of the wires/fibres from the sensors, the ends joining to leads (not shown) in Cable 15 which extends from the junction boxes of other sensor pipes 1 above and below pipe 1 of Fig.3 leading to the data analysis system.
  • Each slot or groove may be individually capped (e.g. as shown with threaded lid 35 on slot 8) or a thin sheath cap may surround all the slots or grooves, e.g. by generally surrounding the thicker wall portion 31.
  • the pipe of Fig.3 is used in the same way as the pipe of Fig.1.

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  • Physics & Mathematics (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Geophysics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Testing Or Calibration Of Command Recording Devices (AREA)

Abstract

La présente invention concerne un tube de complétion (1) d'un réservoir de pétrole/gaz disposant d'au moins un capteur extérieur, par exemple, 2 à 6 capteurs, de sorte qu'une électrode à résistivité (6), un capteur manométrique (7) ou un capteur thermique (9), l'un d'entre eux au moins étant de préférence situé à l'extérieur du tube, est maintenu au moyen d'un cerclage, d'un cadre ou d'un logement fixe ou déposable monté à l'extérieur sur le tube. Un procédé de détermination d'un ou de plusieurs paramètres concernant une formation, indiquant, par exemple, une résistivité, une pression et une température règnant au fond d'un réservoir, afin d'obtenir des informations sur les conditions qui y règnent, est exécuté en continu, au cours de la production, en introduisant ledit tube de complétion dans le réservoir et en mesurant le paramètre. On peut également mesurer des paramètres lors d'un soutirage de pétrole et/ou de gaz du réservoir.
PCT/GB1997/002497 1996-09-19 1997-09-12 Dispositif et procede de surveillance WO1998012417A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AU42156/97A AU4215697A (en) 1996-09-19 1997-09-12 Monitoring device and method

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GB9619551.6 1996-09-19
GBGB9619551.6A GB9619551D0 (en) 1996-09-19 1996-09-19 Monitoring device and method

Publications (1)

Publication Number Publication Date
WO1998012417A1 true WO1998012417A1 (fr) 1998-03-26

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PCT/GB1997/002497 WO1998012417A1 (fr) 1996-09-19 1997-09-12 Dispositif et procede de surveillance

Country Status (3)

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AU (1) AU4215697A (fr)
GB (1) GB9619551D0 (fr)
WO (1) WO1998012417A1 (fr)

Cited By (17)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2000000850A1 (fr) * 1998-06-18 2000-01-06 Den Norske Stats Oljeselskap A.S Dispositif et procede permettant de mesurer la resistivite a l'exterieur d'un tube de puits
WO2000049268A1 (fr) * 1999-02-19 2000-08-24 Dresser Industries, Inc. Capteurs montes sur tubage
WO2001006091A1 (fr) 1999-07-20 2001-01-25 Halliburton Energy Services, Inc. Systeme et procede pour gestion de gisement en temps reel
WO2001007754A1 (fr) * 1999-07-23 2001-02-01 Schlumberger Limited Procedes et appareil de surveillance a long terme d'un gisement en hydrocarbures
ES2176054A1 (es) * 1999-08-10 2002-11-16 Union Fenosa Generacion S A Mejoras introducidas en sondas aplicables a recintos o conductos de circulacion de fluidos.
EP1319799A1 (fr) * 2001-12-13 2003-06-18 Services Petroliers Schlumberger Procédé et dispositif pour la complétion de puits
US6853921B2 (en) 1999-07-20 2005-02-08 Halliburton Energy Services, Inc. System and method for real time reservoir management
US7861788B2 (en) 2007-01-25 2011-01-04 Welldynamics, Inc. Casing valves system for selective well stimulation and control
US7950461B2 (en) 2007-11-30 2011-05-31 Welldynamics, Inc. Screened valve system for selective well stimulation and control
WO2011122955A1 (fr) * 2010-03-30 2011-10-06 Aadnoey Bernt Sigve Procédé et dispositif pour déterminer une pression d'essai dans un puits
EP2390461A1 (fr) * 2010-05-31 2011-11-30 Welltec A/S Système de surveillance de puits de forage
CN102518424A (zh) * 2011-12-28 2012-06-27 中国石油天然气集团公司 一种流体电阻率和温度复合测量装置
WO2013184096A1 (fr) * 2012-06-05 2013-12-12 Halliburton Energy Services, Inc. Outils de fond de trou et matériels tubulaires de champ pétrolier ayant des capteurs internes pour une communication externe sans fil
EP2952674A1 (fr) * 2014-06-04 2015-12-09 Services Petroliers Schlumberger Outil de diagraphie de fond de trou rotatif avec couple réduit
CN105201487A (zh) * 2015-09-02 2015-12-30 中国海洋石油总公司 一种深水气田生产期间井筒水合物堵塞监测方法及装置
WO2017066881A1 (fr) * 2015-10-23 2017-04-27 Atomic Energy Of Canada Limited / Énergie Atomique Du Canada Limitée Appareil d'essai et conduit instrumenté destiné à être utilisé avec ce dernier
RU191423U1 (ru) * 2019-05-24 2019-08-05 Публичное акционерное общество «Татнефть» имени В.Д. Шашина Узел крепления корпуса датчиков измерения давления вне и внутри насосно-компрессорной трубы

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Cited By (45)

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Publication number Priority date Publication date Assignee Title
GB2355538A (en) * 1998-06-18 2001-04-25 Norske Stats Oljeselskap Device and method for measurement of resistivity outside of a wellpipe
GB2355538B (en) * 1998-06-18 2003-08-27 Norske Stats Oljeselskap Device and method for measurement of resistivity outside of a wellpipe
WO2000000850A1 (fr) * 1998-06-18 2000-01-06 Den Norske Stats Oljeselskap A.S Dispositif et procede permettant de mesurer la resistivite a l'exterieur d'un tube de puits
US6480000B1 (en) 1998-06-18 2002-11-12 Den Norske Stats Oljeselskap A.S. Device and method for measurement of resistivity outside of a wellpipe
US6429784B1 (en) 1999-02-19 2002-08-06 Dresser Industries, Inc. Casing mounted sensors, actuators and generators
EP1335103A2 (fr) * 1999-02-19 2003-08-13 Dresser Industries Inc. Procédé pour déterminer le durcissement de ciment dans un puits de forage
US6747570B2 (en) 1999-02-19 2004-06-08 Halliburton Energy Services, Inc. Method for preventing fracturing of a formation proximal to a casing shoe of well bore during drilling operations
EP1965021A3 (fr) * 1999-02-19 2009-09-02 Halliburton Energy Services, Inc. Procédé de collecte de données géologiques
US6693554B2 (en) 1999-02-19 2004-02-17 Halliburton Energy Services, Inc. Casing mounted sensors, actuators and generators
US7046165B2 (en) 1999-02-19 2006-05-16 Halliburton Energy Services, Inc. Method for collecting geological data ahead of a drill bit
EP2003287A2 (fr) 1999-02-19 2008-12-17 Halliburton Energy Services, Inc. Procédé de collecte de données géologiques
WO2000049268A1 (fr) * 1999-02-19 2000-08-24 Dresser Industries, Inc. Capteurs montes sur tubage
EP1335103A3 (fr) * 1999-02-19 2006-07-19 Halliburton Energy Services, Inc. Procédé pour déterminer le durcissement de ciment dans un puits de forage
US6853921B2 (en) 1999-07-20 2005-02-08 Halliburton Energy Services, Inc. System and method for real time reservoir management
US7079952B2 (en) 1999-07-20 2006-07-18 Halliburton Energy Services, Inc. System and method for real time reservoir management
WO2001006091A1 (fr) 1999-07-20 2001-01-25 Halliburton Energy Services, Inc. Systeme et procede pour gestion de gisement en temps reel
USRE42245E1 (en) 1999-07-20 2011-03-22 Halliburton Energy Services, Inc. System and method for real time reservoir management
USRE41999E1 (en) 1999-07-20 2010-12-14 Halliburton Energy Services, Inc. System and method for real time reservoir management
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