WO2012128867A2 - Appareil et méthode de filtrage de données influencées par une pompe de fond - Google Patents

Appareil et méthode de filtrage de données influencées par une pompe de fond Download PDF

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Publication number
WO2012128867A2
WO2012128867A2 PCT/US2012/025242 US2012025242W WO2012128867A2 WO 2012128867 A2 WO2012128867 A2 WO 2012128867A2 US 2012025242 W US2012025242 W US 2012025242W WO 2012128867 A2 WO2012128867 A2 WO 2012128867A2
Authority
WO
WIPO (PCT)
Prior art keywords
pump
measurements
measurement
tool
disposed
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.)
Ceased
Application number
PCT/US2012/025242
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English (en)
Other versions
WO2012128867A3 (fr
Inventor
Tobias Kischkat
Eick Niemeyer
Stefan Sroka
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.)
Baker Hughes Holdings LLC
Original Assignee
Baker Hughes 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 Baker Hughes Inc filed Critical Baker Hughes Inc
Priority to BR112013023821A priority Critical patent/BR112013023821A2/pt
Priority to GB1318539.2A priority patent/GB2504029A/en
Publication of WO2012128867A2 publication Critical patent/WO2012128867A2/fr
Publication of WO2012128867A3 publication Critical patent/WO2012128867A3/fr
Priority to NO20131063A priority patent/NO20131063A1/no
Anticipated expiration legal-status Critical
Ceased 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
    • 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
    • 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
    • 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

Definitions

  • the invention disclosed herein relates to filtering data obtained from a downhole environment and, in particular, to data related to using a downhole pump.
  • Drilling apparatus used for geophysical exploration often includes one or more sensors for performing measurements on ambient subsurface materials.
  • the sensors are disposed in a bottomhole assembly located in a drill string in the vicinity of a drill bit. The measurements can be performed while drilling a borehole through the subsurface materials or during a temporary halt in drilling.
  • Mud-pulse telemetry is usually very slow (a few bits per second) taking several seconds to minutes to transmit a whole data package. Because of the low data transmission rate, problems can arise when all the acquired data cannot be transmitted. Usually the latest acquired data available is used for transmission to the surface. However, not all of the latest acquired data is useful and transmission of such data wastes time and bandwidth and can prevent more useful data from being transmitted.
  • One type of sensor used to MWD is a formation tester tool.
  • the formation tester tool is configured to draw formation fluid from a wall of the borehole and to perform one or more tests on the formation fluid sample.
  • a positive displacement pump such as a dual action pump using a piston is typically used to draw the formation fluid sample.
  • the sample is drawn by the piston reducing pressure within a chamber causing the formation fluid, which is at a higher pressure, to flow into the chamber.
  • Sample pressure or a parameter related to sample pressure is generally one type of data required to properly evaluate the sample.
  • Transmitting a value measured during pump reversing is a waste of time and bandwidth because the value it is transmitted at non-predictable intervals. Hence, it would be well received in the drilling industry if the transmission of data from a MWD tool could be improved.
  • the method includes disposing the tool in a borehole and receiving a series of measurements using a processor disposed at the tool.
  • a telemetry system transmits a latest received measurement that meets acceptance criteria to the receiver after completion of transmission of a previously transmitted measurement.
  • an apparatus for transmitting data from a tool configured to be disposed in a borehole penetrating the earth to a receiver.
  • the apparatus includes: a telemetry system disposed at the tool; and a processor disposed at the tool and configured to receive a series of measurements and to identify those measurements that are latest received and meet an acceptance criterion for transmission by the telemetry system to the receiver after completion of transmission of a previously transmitted measurement.
  • a non-transitory computer-readable medium having computer-executable instructions for transmitting data from a tool disposed in a borehole penetrating the earth to a receiver by implementing a method that includes: receiving a series of measurements from a sensor disposed in a borehole; and transmitting a latest received measurement that meets an acceptance criterion to the receiver after completion of transmission of a previously transmitted measurement.
  • FIG. 1 illustrates an exemplary embodiment of a downhole tool disposed in a borehole penetrating the earth
  • FIG. 2 illustrates an exemplary embodiment of a dual-action sample pump
  • FIG. 3 depicts aspects of sample chamber pressure in the sample pump
  • FIGS. 4A and 4B depict further aspects of sample chamber pressure in the sample pump
  • FIGS. 5A and 5B depict aspects of sensor output influenced by pump pressure variation
  • FIG. 6 presents one example of a method for transmitting data from a downhole tool to a receiver.
  • FIG. 1 illustrates an exemplary embodiment of a downhole tool 10 disposed in a borehole 2 penetrating the earth 3, which includes an earth formation 4.
  • the downhole tool 10 is conveyed through the borehole 2 by a carrier 5.
  • the carrier 5 is a drill string 6 for measurement- while- drilling (MWD) operations.
  • the carrier 5 can be a wireline for wireline operations.
  • a telemetry system 7 is provided in order to transmit data from the downhole tool 10 to a receiver such as a computer processing system 13 disposed at the surface of the earth 3.
  • the telemetry system 7 is a mud-pulse telemetry system 8.
  • the downhole tool 10 includes downhole electronics 11.
  • the downhole tool 10 includes a formation fluid tester 12 configured to perform one or more measurements on fluid extracted from the formation 4.
  • the formation fluid tester includes a probe 14 configured to extend from the downhole tool 10 and seal with a wall of the borehole 2.
  • a pump 15 coupled to the probe 14 is configured to lower the pressure internal to the probe 14 in order to draw a sample of formation fluid from the formation 4 and discharge the sample into a sample chamber 16 for analysis.
  • Various sensors 17 are configured to perform various types of measurements on the sample.
  • Non-limiting examples of the measurements include pressure, temperature, density, viscosity, compressibility, radiation, and spectroscopy.
  • the downhole electronics 11 includes a filter 18 configured to process data/measurements from the various sensors 17.
  • the processing can include a filtering function and/or an associating function where each measurement received is associated with some other data such as a measurement of some aspect of the pump 15.
  • the downhole electronics 11 also includes memory 19 configured to store measurements from the sensor 17 as the measurements are received.
  • the memory 19 provides for storing measurements that cannot be immediately transmitted to the computer processing system 13 because of limited bandwidth of the telemetry system 7.
  • FIG. 2 illustrating an exemplary embodiment of the pump 15.
  • the pump 15 is a dual-action pump (i.e., pumping fluid on both strokes of a piston).
  • a piston in pump 15 is used to displace fluid to cause the pumping.
  • valves 21 and 22 act as inlet valves and valves 23 and 24 act as outlet valves.
  • Valves 21-24 can be check- valves or externally driven valves.
  • Coupled to the pump 15 is a pump sensor 20.
  • the pump sensor 20 is configured to measure one or more aspects of the pump 15. As non- limiting examples, the pump sensor 20 can measure inlet pressure, outlet pressure, piston position, pump flow rate, and/or volume pumped.
  • FIG. 3 presents a pressure curve of a dual-action pump for one of the inlet sides of the pump.
  • transmission of the latest data acquired is the transmission of the latest data obtained while the piston is moving.
  • the returned data is either (case 1) the latest value if the piston is currently moving or (case 2) an older value (stored in memory) that was acquired while the piston was moving if the piston is currently reversing.
  • the pressure needs some time to stabilize again.
  • a further improvement to the above method is to include some time for piston movement after piston reversal such as in case 2. This additional time can be defined by a specific or set time, a volume pumped, a flow rate, or data stability of some sensor data.
  • each of the required conditions for data to be transmitted to the receiver may be referred to as an acceptance criterion.
  • the techniques for determining which data to transmit can be extended from pump inlet pressure measurement to other data.
  • Downhole fluid sampling tools may contain fluid sensors for fluid contamination estimation or fluid identification or characterization. The output of these sensors can be pressure dependent. If a pressure variation is caused by the pump and influences the sensor data, an algorithm can be used to determine and transmit consistent data (i.e., data taken under approximately the same conditions). This way, a tool operator can better assess if variation in sensor data is caused by a change in fluid properties. It reduces the probability for misinterpretation because the transmitted data shows less variation and is known to be more consistent and, thus, yield more accurate data.
  • the operator must make sure that the inlet pump pressure does not get below a threshold pressure (e.g., bubble point) at which the fluid properties change irreversibly.
  • a threshold pressure e.g., bubble point
  • the tool operator is usually interested in the lower pressures.
  • one additional type of data to transmit is the lowest pump inlet pressure, which has occurred in a certain timeframe. This value helps the tool operator to decide if the pump speed must be adjusted to stay above the bubble point.
  • the timeframe can be defined by a time interval, volume, or telemetry update rate as non-limiting examples.
  • the idea of sending additional data to help interpret the primary data sent can be extended to other sensor data that is influenced by pressure or flow rate variation and where minimum, maximum, or other statistical values are important for the tool operator to know when the data transmission rate is too low to determine these values after transmission of raw data.
  • the time to fill a pump chamber can be long.
  • Fluid entering the pump chamber may contain immiscible components or components featuring high difference in density.
  • a long staying time in the pump chamber can lead to segregation of the fluid components.
  • the components When the segregated fluid is pushed out of the chamber, the components may leave the chamber successively, influencing the fluid sensors successively as well. Usually, this leads to random noise in the telemetry data.
  • the measured data can be separated into data acquired at the beginning of a pump stroke from the data acquired at the end of the pump stroke. Thus, consistent data for the individual fluid components is transmitted.
  • Extraction and transmission of data acquired while the pump is reversing can give information about mobility (i.e., higher mobility leads to higher pressure or faster pressure stabilization at formation pressure during stopping of flow). Pressure rising above formation pressure during stopping of flow is an indicator for loss of seal with the formation. This information is very important because the loss of seal usually cannot be remedied except by aborting tool operation, releasing the seal element, moving the tool to a different location and trying to achieve a seal at the new location. Hence, for these reasons it may be desirable to transmit data obtained during reversal of the pump piston.
  • Some sensors are influenced by the pressure or flow rate variations caused by the pump. Some measurements take a long time to deliver a result, or long time response filters are involved in post-processing of the measurements. If this timeframe overlaps with pump piston reversal, the sensor data quality will suffer.
  • a sensor is influenced by the pressure or flow rate variations caused by the pump. Its data is acquired at a high rate and filtered by a filter with a filter response time of several seconds. The pressure change during pump piston reversal generates biased acquired data and the filtered data will still be biased for some time after the pump piston reversal has been executed because of the filter delay.
  • a sensor is influenced by pump pressure variation.
  • a measurement takes several seconds.
  • the sensor might feature a variation of a resonance frequency as response to a parameter of interest.
  • the resonance has to be determined by applying a frequency sweep. This can take several seconds. If a pressure variation occurs during the sweep, the acquired spectrum is distorted (maybe showing several resonance peeks or none at all) and the result can be of limited value or useless.
  • sensor data acquisition can be paused during pump piston reversal. Sensor data acquisition is then resumed after pump piston reversal when the pump inlet pressure is stable again. If the pump piston position is known, the data acquisition can already be paused when the pump piston reversal is imminent. Pausing can include (1) stopping data acquisition completely and stopping the associated filtering as well (such as when using digital filters), (2) feeding the last good value (i.e., stable constant value) into the filter, (3) stopping a measurement sequence and resuming it later (for example, stopping the frequency sweep at the current frequency and resuming the frequency sweep at that frequency later), and (4) discarding already acquired data of a measurement sequence and restarting the sequence later.
  • FIG. 4A shows one example of original (i.e., unfiltered) data for pump pressure versus time while FIG. 4B shows that data after filtering (i.e., cleaned-up post processing data).
  • FIG. 5A shows another example of original unfiltered data, in this case sound speed versus time, while FIG. 5B shows that data after filtering.
  • the fluid's density, sound speed and refractive index pi, ci and respectively, during flow phase are given as are the fluid's sound speed and refractive index C2 and ri2 during no-flow phase. Because the polarizability of the fluid is not changed during the short flow stop, the density p 2 can be calculated following Clausius-Mosotti equation, as explained in patent US 7,016,026 B2 using equation (2).
  • FIG. 6 presents one example of a method 60 for transmitting data from a tool disposed in a borehole penetrating the earth to a receiver.
  • the method 60 calls for (step 61) disposing the tool in a borehole using a carrier. Further, the method 60 calls for (step 62) receiving a series of measurements using a processor disposed at the tool. Further, the method 60 calls for (step 63) transmitting a latest received measurement that meets an acceptance criterion to the receiver after completion of transmission of a previously transmitted measurement using a telemetry system.
  • various analysis components may be used, including a digital and/or an analog system.
  • the downhole electronics 11, the computer processing system 13, or the filter 18 may include the digital and/or analog system.
  • the system may have components such as a processor, storage media, memory, input, output, communications link (wired, wireless, pulsed mud, optical or other), user interfaces, software programs, signal processors (digital or analog) and other such components (such as resistors, capacitors, inductors and others) to provide for operation and analyses of the apparatus and methods disclosed herein in any of several manners well-appreciated in the art.
  • teachings may be, but need not be, implemented in conjunction with a set of computer executable instructions stored on a computer readable medium, including memory (ROMs, RAMs), optical (CD-ROMs), or magnetic (disks, hard drives), or any other type that when executed causes a computer to implement the method of the present invention.
  • ROMs, RAMs random access memory
  • CD-ROMs compact disc-read only memory
  • magnetic (disks, hard drives) any other type that when executed causes a computer to implement the method of the present invention.
  • These instructions may provide for equipment operation, control, data collection and analysis and other functions deemed relevant by a system designer, owner, user or other such personnel, in addition to the functions described in this disclosure.
  • a power supply e.g., at least one of a generator, a remote supply and a battery
  • cooling component heating component
  • magnet, electromagnet, sensor, electrode, transmitter, receiver, transceiver, antenna controller
  • optical unit, electrical unit or electromechanical unit may be included in support of the various aspects discussed herein or in support of other functions beyond this disclosure.
  • carrier means any device, device component, combination of devices, media and/or member that may be used to convey, house, support or otherwise facilitate the use of another device, device component, combination of devices, media and/or member.
  • Other exemplary non-limiting carriers include drill strings of the coiled tube type, of the jointed pipe type and any combination or portion thereof.
  • Other carrier examples include casing pipes, wirelines, wireline sondes, slickline sondes, drop shots, bottom-hole-assemblies, drill string inserts, modules, internal housings and substrate portions thereof.

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  • Physics & Mathematics (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geophysics (AREA)
  • Geology (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Remote Sensing (AREA)
  • General Physics & Mathematics (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Acoustics & Sound (AREA)
  • Geophysics And Detection Of Objects (AREA)
  • Measuring Fluid Pressure (AREA)
  • Arrangements For Transmission Of Measured Signals (AREA)
  • Investigation Of Foundation Soil And Reinforcement Of Foundation Soil By Compacting Or Drainage (AREA)

Abstract

Une méthode de transmission à un récepteur de données provenant d'un outil disposé dans un trou de sonde pénétrant dans la terre est divulguée. Ladite méthode consiste à placer l'outil dans un trou de sonde et à recevoir une série de mesures au moyen d'un processeur placé au niveau de l'outil. Un système de télémétrie transmet au récepteur la dernière mesure reçue conforme aux critères d'acceptation une fois la transmission d'une mesure transmise antérieurement effectuée.
PCT/US2012/025242 2011-03-24 2012-02-15 Appareil et méthode de filtrage de données influencées par une pompe de fond Ceased WO2012128867A2 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
BR112013023821A BR112013023821A2 (pt) 2011-03-24 2012-02-15 "método e aparelho para transmitir dados de uma ferramenta para um receptor".
GB1318539.2A GB2504029A (en) 2011-03-24 2012-02-15 Apparatus and method for filtering data influenced by a downhole pump
NO20131063A NO20131063A1 (no) 2011-03-24 2013-08-05 Apparat og fremgangsmåte for filtrering av data påvirket av en nedihullspumpe

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201161467262P 2011-03-24 2011-03-24
US61/467,262 2011-03-24

Publications (2)

Publication Number Publication Date
WO2012128867A2 true WO2012128867A2 (fr) 2012-09-27
WO2012128867A3 WO2012128867A3 (fr) 2012-12-06

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Country Link
US (1) US20130020074A1 (fr)
BR (1) BR112013023821A2 (fr)
GB (1) GB2504029A (fr)
NO (1) NO20131063A1 (fr)
WO (1) WO2012128867A2 (fr)

Cited By (2)

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CN103195415A (zh) * 2013-03-27 2013-07-10 中国石油天然气集团公司 一种用于钻井工程中的井下高速信息传输系统及方法
EP3017199A4 (fr) * 2013-07-03 2017-02-22 Services Pétroliers Schlumberger Détermination acoustique d'une position de piston dans une pompe volumétrique de testeur dynamique modulaire et procédés permettant de fournir des estimations d'un débit de fluide

Families Citing this family (4)

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KR101091807B1 (ko) * 2011-05-18 2011-12-13 한국지질자원연구원 유전율 센서를 이용한 암석 및 단층점토의 유전율 측정장치
US9958849B2 (en) * 2013-02-20 2018-05-01 Schlumberger Technology Corporation Cement data telemetry via drill string
US20150176389A1 (en) * 2013-12-20 2015-06-25 Schlumberger Technology Corporation Detection And Identification Of Fluid Pumping Anomalies
US9932824B2 (en) 2015-10-21 2018-04-03 Schlumberger Technology Corporation Compression and transmission of measurements from downhole tool

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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
US6799602B2 (en) * 2001-12-28 2004-10-05 Visteon Global Technologies, Inc. Combination fitting
US6675914B2 (en) * 2002-02-19 2004-01-13 Halliburton Energy Services, Inc. Pressure reading tool
GB2399921B (en) * 2003-03-26 2005-12-28 Schlumberger Holdings Borehole telemetry system
US7124819B2 (en) * 2003-12-01 2006-10-24 Schlumberger Technology Corporation Downhole fluid pumping apparatus and method
US8826988B2 (en) * 2004-11-23 2014-09-09 Weatherford/Lamb, Inc. Latch position indicator system and method
US20060132327A1 (en) * 2004-12-21 2006-06-22 Baker Hughes Incorporated Two sensor impedance estimation for uplink telemetry signals
WO2006122174A2 (fr) * 2005-05-10 2006-11-16 Baker Hughes Incorporated Appareil de telemetrie bidirectionnelle et procedes de fonctionnement d'un puits de forage
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WO2009025688A1 (fr) * 2007-08-20 2009-02-26 Halliburton Energy Services, Inc. Appareil et procédé pour des mesures de propriété de fluide
US20090066334A1 (en) * 2007-09-10 2009-03-12 Baker Hughes Incorporated Short Normal Electrical Measurement Using an EM-Transmitter
US20090120689A1 (en) * 2007-11-12 2009-05-14 Baker Hughes Incorporated Apparatus and method for communicating information between a wellbore and surface
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Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN103195415A (zh) * 2013-03-27 2013-07-10 中国石油天然气集团公司 一种用于钻井工程中的井下高速信息传输系统及方法
EP3017199A4 (fr) * 2013-07-03 2017-02-22 Services Pétroliers Schlumberger Détermination acoustique d'une position de piston dans une pompe volumétrique de testeur dynamique modulaire et procédés permettant de fournir des estimations d'un débit de fluide

Also Published As

Publication number Publication date
NO20131063A1 (no) 2013-09-02
GB2504029A (en) 2014-01-15
WO2012128867A3 (fr) 2012-12-06
BR112013023821A2 (pt) 2016-12-13
US20130020074A1 (en) 2013-01-24
GB201318539D0 (en) 2013-12-04

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