EP0908600A2 - Dispositif pour l'essai de formations - Google Patents

Dispositif pour l'essai de formations Download PDF

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Publication number
EP0908600A2
EP0908600A2 EP98308218A EP98308218A EP0908600A2 EP 0908600 A2 EP0908600 A2 EP 0908600A2 EP 98308218 A EP98308218 A EP 98308218A EP 98308218 A EP98308218 A EP 98308218A EP 0908600 A2 EP0908600 A2 EP 0908600A2
Authority
EP
European Patent Office
Prior art keywords
fluid
formation
pressure
pressure sensor
filter
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.)
Withdrawn
Application number
EP98308218A
Other languages
German (de)
English (en)
Other versions
EP0908600A3 (fr
Inventor
Neal G. Skinner
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.)
Halliburton Energy Services Inc
Original Assignee
Halliburton Energy Services Inc
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 Halliburton Energy Services Inc filed Critical Halliburton Energy Services Inc
Publication of EP0908600A2 publication Critical patent/EP0908600A2/fr
Publication of EP0908600A3 publication Critical patent/EP0908600A3/fr
Withdrawn legal-status Critical Current

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • 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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/124—Units with longitudinally-spaced plugs for isolating the intermediate space
    • E21B33/1243—Units with longitudinally-spaced plugs for isolating the intermediate space with inflatable sleeves
    • 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
    • E21B47/06—Measuring temperature or pressure
    • 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
    • E21B47/12—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
    • E21B47/14—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 using acoustic waves
    • E21B47/18—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 using acoustic waves through the well fluid, e.g. mud pressure pulse telemetry
    • 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
    • E21B49/10—Obtaining fluid samples or testing fluids, in boreholes or wells using side-wall fluid samplers or testers

Definitions

  • the present invention relates generally to operations and equipment for use in a subterranean well and, in an embodiment described herein, more particularly provides formation testing apparatus and methods of testing a formation. More particularly the present invention relates to formation testing apparatus, and associated methods, having noise reduction capability.
  • fluid pressure pulses In operations performed in a subterranean well, it is quite common for data to be transmitted via fluid pressure pulses in the wellbore. This type of data transmission is typically referred to as "mud pulse telemetry".
  • fluid is circulated from the earth's surface to a downhole tool which periodically restricts, or otherwise changes, the rate of flow of the circulating fluid therethrough, thereby creating variations in the pressure of the circulating fluid.
  • the pressure pulses (the frequency of which are typically on the order of about 1 Hz) are then detected at the earth's surface and the data decoded therefrom.
  • fluid pressure pulses may interfere with other operations in the well. For example, it is known that fluid pressure pulses may enter into a formation intersected by the wellbore and change the pressure of the fluid within the formation. This can result in inaccurate measurements of the formation fluid pressure taken by a formation testing tool.
  • fluid is drawn into the tool from the formation.
  • the pressure of the fluid is measured both before, during, and after it is drawn into the tool. These measurements are then utilized to calculate characteristics of the formation and predict its future productivity. Inaccuracies in these measurements may frustrate attempts to characterize the formation, leading to loss of production from the formation or loss of resources expended in producing the formation.
  • apparatus which is a formation testing tool.
  • the tool is capable of taking accurate measurements of formation fluid pressure, even though the formation fluid pressure may be influenced by pressure pulses in the wellbore. Associated methods are also provided.
  • apparatus which includes a pressure sensor coupled to an appropriately configured filter.
  • the pressure sensor may be placed in fluid communication with a formation intersected by the well.
  • An output of the pressure sensor may include combined indications of the formation fluid pressure and pressure pulses corresponding to the pressure pulses in the wellbore.
  • the filter removes the pressure pulse indications from the pressure sensor output.
  • the filter may be constructed to pass the formation fluid pressure frequencies while filtering out the pressure pulse frequencies. For example, if it is known that the formation fluid pressure frequency is less than the pressure pulse frequency, the filter may be provided as a low pass filter.
  • filters may be utilized as well.
  • another pressure sensor may be provided and placed in fluid communication with the wellbore or other location in which the pressure pulses are transmitted.
  • the output of this pressure sensor may then be coupled to the filter, so that the filter is capable of determining the contribution of the pressure pulses to the output of the formation fluid pressure sensor.
  • the filter may then operate to remove this pressure pulse contribution from the formation fluid pressure sensor output.
  • filters usable in the apparatus and having these capabilities are adaptive filters and neural network filters, which are well known to those of ordinary skill in the signal filtering art.
  • a formation testing apparatus for use within a wellbore, comprising a first fluid passage for receiving fluid therein from a formation intersecting the wellbore; a first fluid pressure sensor interconnected to the first fluid passage; and a filter coupled to the first pressure sensor.
  • the apparatus can be used within a wellbore of the type in which fluid pressure pulses having a first frequency are communicated with the formation.
  • the apparatus can be used in a wellbore of the type in which the formation fluid pressure is influenced in part by pressure pulses in the wellbore.
  • the apparatus may further comprise a sealing device configured for sealingly engaging at least a portion of the formation, the sealing device being disposed relative to the first fluid passage such that the first fluid passage is in fluid communication with the formation when the sealing device sealingly engages the formation.
  • the apparatus further comprises: a second fluid passage for receiving fluid therein from the wellbore; and a second fluid pressure sensor interconnected to the second fluid passage, the second pressure sensor being capable of sensing the fluid pressure pulses, and an output of the second pressure sensor being coupled to the filter.
  • the filter is preferably an adaptive filter or a neural network filter, rather than a low pass filter.
  • a fluid testing apparatus for use within a wellbore wherein fluid pressure pulses having a first frequency are communicated with a formation intersected by the wellbore, comprising: a first fluid passage for receiving fluid therein from the formation; a first fluid pressure sensor interconnected to the first fluid passage, the sensor being capable of sensing a combination of the fluid pressure pulses and the pressure of the fluid received from the formation, and the first pressure sensor producing an output; and a filter coupled to the first pressure sensor, the filter being capable of removing indications of the fluid pressure pulses from the first pressure sensor output.
  • the filter is a low pass filter configured to remove the first frequency from the first pressure sensor output.
  • a second fluid pressure frequency is imparted to the fluid received into the first fluid passage due to receiving the fluid into the first fluid passage, and the filter passes the second frequency but removes the first frequency from the first pressure sensor output.
  • the second frequency may be less than the first frequency.
  • the low pass filter may be configured to pass frequencies less than a third frequency between the first and second frequencies.
  • the low pass filter may be configured to pass frequencies up to and including the second frequency.
  • the apparatus further comprises: a second fluid passage for receiving fluid therein from the wellbore; and a second fluid pressure sensor interconnected to the second fluid passage, the second pressure sensor being capable of sensing the fluid pressure pulses, and an output of the second pressure sensor being coupled to the filter.
  • the filter may be an adaptive filter capable of removing indications of the fluid pressure pulses from the first pressure sensor output based on the second fluid pressure sensor output.
  • the filter may be a neural network filter capable of removing indications of the fluid pressure pulses from the first pressure sensor output based on the second fluid pressure sensor output.
  • formation testing apparatus for sensing the pressure of fluid received into the apparatus from a formation intersected by a wellbore, the formation fluid pressure being influenced in part by pressure pulses in the wellbore
  • the apparatus comprising: a sealing device configured for sealingly engaging at least a portion of the formation; a first fluid passage disposed relative to the sealing device such that the first fluid passage is in fluid communication with the formation when the sealing device sealingly engages the formation; a first fluid pressure sensor in fluid communication with the first fluid passage; and a filter coupled to the first fluid pressure sensor.
  • the filter may be a low pass filter.
  • the sealing device is configured to substantially isolate the portion of the formation from a portion of the wellbore when the sealing device sealingly engages the formation.
  • the apparatus further comprises a second fluid passage disposed relative to the sealing device such that the second fluid passage is in fluid communication with the portion of the wellbore and is capable of receiving the pressure pulses therein.
  • the apparatus may further comprise a second fluid pressure sensor in fluid communication with the second fluid passage.
  • the second pressure sensor may be coupled to the filter.
  • the filter may be an adaptive filter or a neural network filter.
  • a method of measuring the pressure of fluid received in a testing apparatus from a formation intersected by a wellbore in the presence of fluid pressure pulses transmitted to the formation comprising the steps of: interconnecting a first fluid pressure sensor to a first fluid passage in fluid communication with the formation; producing an output of the first pressure sensor including indications of the formation fluid pressure and the pressure pulses; coupling the first pressure sensor output to a filter; and filtering out the indications of the pressure pulses from the first pressure sensor output.
  • the filter may be a low pass filter.
  • the filtering step may be performed by passing indications in the first pressure sensor output which have frequencies less than a predetermined frequency, and removing indications in the first pressure sensor output which have frequencies greater than the predetermined frequency.
  • the method may further comprise the steps of: interconnecting a second fluid pressure sensor to a second fluid passage in fluid communication with the wellbore; producing an output of the second pressure sensor including an indication of the pressure pulses; and coupling the second pressure sensor to the filter.
  • the filtering step may further comprise adapting the filter to the indication of the pressure pulses output by the second pressure sensor.
  • the filter may be an adaptive filter or a neural network filter.
  • a method of removing extraneous fluid pressure indications from an output of a first pressure sensor in fluid communication with a formation intersected by a wellbore comprising the steps of: coupling the first pressure sensor output to a filter; and permitting indications in the first pressure sensor output other than the extraneous fluid pressure indications to pass through the filter.
  • the filter may be a low pass filter.
  • the method may further comprise the steps of: coupling a second pressure sensor output to the filter.
  • the second pressure sensor output may include indications of the extraneous fluid pressure.
  • the filter may be an adaptive filter or a neural network.
  • FIG 1 Representatively illustrated in FIG 1 is a formation testing tool 10 which embodies principles of the present invention.
  • directional terms such as “above”, “below”, “upper”, “lower”, etc., are used for convenience in referring to the accompanying drawings. Additionally, it is to be understood that the various embodiments of the present invention described herein may be utilized in various orientations, such as inclined, inverted, horizontal, vertical, etc., without departing from the principles of the present invention.
  • the tool 10 is shown disposed within a wellbore 12 of a well.
  • the wellbore 12 intersects a formation, or interval of a formation, 14 from which it is desired to obtain fluid pressure measurements.
  • the tool 10 is of the well known type which has a laterally outwardly extendable fluid sampling portion 16 including a sealing device 18 for contacting and sealingly engaging the formation 14. In this manner, a portion 20 of the formation 14 is substantially isolated from the remainder of the wellbore 12 external to the sealing device 18.
  • a fluid passage 22 extends into the interior of the tool 10 and is in fluid communication with the formation portion 20.
  • a piston 24 When a piston 24 is stroked downwardly as viewed in FIG. 1, fluid is drawn into the fluid passage 22 from the formation 14.
  • the pressure of the formation fluid is sensed by a fluid pressure sensor 26, which is in fluid communication with the fluid passage 22.
  • An axial fluid conduit 28 is formed through the tool 10. Via a tubular string (not shown) attached to the tool 10 and extending to the earth's surface, the fluid conduit 28 is utilized to permit circulation of fluid (indicated by arrows 30), such as drilling mud, downwardly through the tool 10 and then axially upward back to the earth's surface through the wellbore 12.
  • fluid indicated by arrows 30
  • Other equipment such as conventional mud motors, mud pulse telemetry tools, tubular strings, etc. (not shown) may be connected to the tool 10 and extend downwardly therefrom.
  • a mud pulse telemetry tool may be utilized to generate data-carrying pressure pulses in the circulating fluid, so that the pressure pulses may be received at the earth's surface and decoded.
  • pressure pulses may be present in the fluid 30 due to other causes, may be present whether or not the fluid is simultaneously being circulated through the well, and the fluid may be circulated in a reverse direction or not circulated at all.
  • other pressure pulse sources and other dispositions of the fluid 30 may be utilized without departing from the principles of the present invention.
  • the fluid 30 contacts the formation 14, even though it may be substantially isolated from the formation portion 20 by the sealing device 18. It will be readily appreciated by one of ordinary skill in the art that pressure pulses in the fluid 30 may be transmitted into the formation 14 via those areas of the formation intersected by the wellbore 12 and external to the sealing device 18. It will also be appreciated that the pressure pulses may be transmitted through the formation 14 to the portion 20 and influence the pressure of the formation fluid drawn into the fluid passage 22. Thus, the pressure sensor 26 may produce an output which indicates a combination of the formation fluid pressure and the pressure pulses transmitted into and through the formation 14 to the portion 20.
  • the tool 10 includes features which remove the indications of the pressure pulses from the pressure sensor 26 output, thereby enhancing the accuracy of the formation fluid pressure measurements obtained by the tool.
  • One method 32 of accomplishing this objective is representatively illustrated in block diagram form in FIG. 3.
  • the pressure sensor 26 is shown as a pressure transducer whose output 34 is coupled via a frequency to voltage converter 36 to a low pass filter 38.
  • the frequency to voltage converter 36 is preferred where the pressure sensor 26 is of the type which has a frequency output 34. However, where a sensor 26 having a voltage output is used, the converter 36 is not needed. Additionally, it is to be clearly understood that it is not necessary for the pressure sensor output 34 to be voltage modulated, or for the output to be converted from frequency to voltage modulated, in accordance with the principles of the present invention.
  • the filter 38 is preferably a low pass filter as shown in FIG. 3. It is believed that, in most circumstances. the frequency of the pressure pulses transmitted from the fluid 30, through the formation 14 and to the portion 20 will be substantially greater than the frequency of the formation fluid pressure which would be sensed in the absence of the pressure pulses.
  • the frequency of the pressure pulses may be about 1 Hz
  • the formation fluid pressure may be about 0.5 Hz (due to drawdown of fluid from the formation 14 into the tool 10, and subsequent fluid pressure buildup, etc.)
  • the filter 38 may be configured to pass the formation fluid pressure frequencies but block passage of the pressure pulse frequencies.
  • the filter 38 could be configured to pass frequencies less than about 0.75 Hz, but block frequencies above about 0.75 Hz.
  • the filter 38 may be configured to pass frequencies equal to or less than the formation fluid pressure frequency.
  • other types of filters may be used for the filter 38, and other configurations of the filter may be utilized, without departing from the principles of the present invention.
  • the pressure sensor output 34 is connected to a conventional recorder and/or telemetry module 40.
  • the output 34 may be recorded in the tool 10 for later retrieval, or transmitted directly to the earth's surface, for example, via mud pulse telemetry, other acoustic telemetry, electromagnetic waves, wireline connected to the tool 10, etc.
  • Other sensors and types of sensors may be connected to the recorder/telemetry module 40 as well.
  • a temperature sensor 42 may be included in the tool 10 for measuring the temperature of the formation fluid or of the wellbore 12 at the formation 14.
  • FIG. 4 Another method 44 of enhancing the accuracy of the formation fluid pressure measurements taken by the tool 10 is representatively depicted in block diagram form in FIG. 4.
  • the method 44 utilizes an additional pressure sensor 46 to detect the pressure pulses in the wellbore 12.
  • the sensor 46 may be seen included in the tool 10 and in fluid communication with a fluid passage 48 which, in turn, is in fluid communication with the wellbore 12.
  • the additional sensor 46 and fluid passage 48 are not needed in the tool 10.
  • the output 34 of the sensor 26 (which includes indications of both the pressure pulses and of the formation fluid pressure) and an output 50 of the sensor 46 (which includes an indication of the pressure pulses in the fluid 30) are coupled to a filter 52.
  • the filter 52 is of the type that removes extraneous signals (also termed "noise") based at least in part on a separate detection of the extraneous signals.
  • This type of filter is well known to a person of ordinary skill in the signal filtering art and examples thereof may be found in a publication entitled Neural Network Design by M.T. Hagan et al., published in 1996 by PWS Publishing Co., Boston, Mass., the disclosure of which is incorporated herein by this reference.
  • Another example of a type of filter which may be used for the filter 52 is an adaptive filter, also well known to a person of ordinary skill in the art.
  • FIG. 2 another formation testing tool 54 embodying principles of the present invention is schematically and representatively illustrated. Elements shown in FIG. 2 which are similar to those previously described are indicated in FIG. 2 using the same reference number, with an added suffix "a".
  • the tool 54 is of the type having an upper portion 56 axially reciprocably disposed relative to a lower portion 58.
  • the lower portion 58 is positioned opposite the formation 14a and a pair of axially spaced apart inflatable packer elements 60 are inflated, so that they radially outwardly extend into sealing engagement with the formation 14a. In this manner, a portion 62 of the formation 14a is substantially isolated from the remainder of the wellbore 12a.
  • An example of this type of tool is the RT031 and RT032 available from Halliburton Energy Services.
  • portion 62 differs from the previously described portion 20 in that the portion 62 extends circumferentially about the tool 54 and the packer elements 60 effectively isolate an upper portion 64 of the wellbore 12a from a lower portion 66 of the wellbore.
  • the fluid passage 22a is in fluid communication with the formation portion 62, and so. when the upper tool portion 56 is axially upwardly displaced relative to the lower portion 58, fluid from the formation 14a is drawn into the fluid passage 22a, and its pressure is measured by the pressure sensor 26a.
  • the pressure pulses in the wellbore 12a may be caused by mud pulse telemetry or may originate at another source. If mud pulse telemetry is utilized, the fluid 30a may be circulated from the earth's surface. downwardly through a tubular string (not shown) attached above the tool 54, outwardly through a radially extending fluid passage 68 to the upper wellbore portion 64, and upwardly to the earth's surface. Thus, the pressure pulses may be present in the upper wellbore portion 64, but not in the lower wellbore portion 66. Nevertheless, the pressure pulses may still be communicated through the formation 14a to the portion 62.
  • the additional pressure sensor 46a may be installed in the tool 54 with the fluid passage 48a providing fluid communication between the wellbore 12a and the pressure sensor 46a.
  • the fluid passage 48a should be in fluid communication with the upper wellbore portion, but it may additionally be placed in fluid communication with the lower wellbore portion 66 if desired.
  • the tool 54 demonstrates that the methods 32, 44 may be utilized with a variety of tools, that it is not necessary for the pressure pulses to be present in the entire wellbore, and that other manners of sealingly engaging and drawing fluid from the formation 14a may be utilized, without departing from the principles of the present invention.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Geophysics (AREA)
  • Remote Sensing (AREA)
  • Acoustics & Sound (AREA)
  • Measuring Fluid Pressure (AREA)
EP98308218A 1997-10-09 1998-10-08 Dispositif pour l'essai de formations Withdrawn EP0908600A3 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US94780597A 1997-10-09 1997-10-09
US947805 1997-10-09

Publications (2)

Publication Number Publication Date
EP0908600A2 true EP0908600A2 (fr) 1999-04-14
EP0908600A3 EP0908600A3 (fr) 2000-12-20

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Application Number Title Priority Date Filing Date
EP98308218A Withdrawn EP0908600A3 (fr) 1997-10-09 1998-10-08 Dispositif pour l'essai de formations

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EP (1) EP0908600A3 (fr)
NO (1) NO984694L (fr)

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2002037072A2 (fr) * 2000-10-27 2002-05-10 Baker Hughes Incorporated Appareil et procede d'essai des formations en cours de forage a l'aide d'une mesure de la pression absolue et differentielle
WO2007081651A2 (fr) * 2006-01-16 2007-07-19 Halliburton Energy Services, Inc. Filtrage et detection de données de télémetrie

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Publication number Priority date Publication date Assignee Title
US4125163A (en) * 1977-12-02 1978-11-14 Basic Sciences, Inc. Method and system for controlling well bore fluid level relative to a down hole pump
US4893505A (en) * 1988-03-30 1990-01-16 Western Atlas International, Inc. Subsurface formation testing apparatus
US4860581A (en) * 1988-09-23 1989-08-29 Schlumberger Technology Corporation Down hole tool for determination of formation properties
WO1992001955A1 (fr) * 1990-07-16 1992-02-06 Atlantic Richfield Company Transducteur de force de torsion et procede de fonctionnement
US5130705A (en) * 1990-12-24 1992-07-14 Petroleum Reservoir Data, Inc. Downhole well data recorder and method
US5473939A (en) * 1992-06-19 1995-12-12 Western Atlas International, Inc. Method and apparatus for pressure, volume, and temperature measurement and characterization of subsurface formations
US5644076A (en) * 1996-03-14 1997-07-01 Halliburton Energy Services, Inc. Wireline formation tester supercharge correction method

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
M.T HAGAN ET AL, NEURAL NETWORK DESIGN BY PWS PUBLISHING CO, 1 January 1996 (1996-01-01), BOSTON

Cited By (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2002037072A2 (fr) * 2000-10-27 2002-05-10 Baker Hughes Incorporated Appareil et procede d'essai des formations en cours de forage a l'aide d'une mesure de la pression absolue et differentielle
WO2002037072A3 (fr) * 2000-10-27 2003-06-05 Baker Hughes Inc Appareil et procede d'essai des formations en cours de forage a l'aide d'une mesure de la pression absolue et differentielle
WO2007081651A2 (fr) * 2006-01-16 2007-07-19 Halliburton Energy Services, Inc. Filtrage et detection de données de télémetrie
WO2007081651A3 (fr) * 2006-01-16 2007-11-22 Halliburton Energy Serv Inc Filtrage et detection de données de télémetrie
GB2448634A (en) * 2006-01-16 2008-10-22 Halliburton Energy Serv Inc Filtering and detection of telemetry
US7480207B2 (en) 2006-01-16 2009-01-20 Halliburton Energy Services, Inc. Filtering and detection of telemetry
GB2448634B (en) * 2006-01-16 2011-03-30 Halliburton Energy Serv Inc Filtering and detection of telemetry
AU2006335022B2 (en) * 2006-01-16 2012-03-01 Halliburton Energy Services, Inc. Filtering and detection of telemetry
NO343171B1 (no) * 2006-01-16 2018-11-19 Halliburton Energy Services Inc Deteksjon og filtrering av kodede telemetridata fra brønner

Also Published As

Publication number Publication date
EP0908600A3 (fr) 2000-12-20
NO984694D0 (no) 1998-10-08
NO984694L (no) 1999-04-12

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