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WO2016167860A1 - Cartographie de fractures hydrauliques à travers tubage - Google Patents

Cartographie de fractures hydrauliques à travers tubage Download PDF

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Publication number
WO2016167860A1
WO2016167860A1 PCT/US2016/017015 US2016017015W WO2016167860A1 WO 2016167860 A1 WO2016167860 A1 WO 2016167860A1 US 2016017015 W US2016017015 W US 2016017015W WO 2016167860 A1 WO2016167860 A1 WO 2016167860A1
Authority
WO
WIPO (PCT)
Prior art keywords
control unit
transmitters
receivers
amplifier
bucking
Prior art date
Application number
PCT/US2016/017015
Other languages
English (en)
Inventor
Qing H. LIU
Zhiru YU
Jianyang ZHOU
Original Assignee
Duke University
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 Duke University filed Critical Duke University
Publication of WO2016167860A1 publication Critical patent/WO2016167860A1/fr

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Classifications

    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V3/00—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation
    • G01V3/18—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation specially adapted for well-logging
    • G01V3/26—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation specially adapted for well-logging operating with magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device
    • G01V3/28—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation specially adapted for well-logging operating with magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device using induction coils

Definitions

  • the present disclosure relates to earth fracture mapping. More particularly, the present disclosure relates to systems and methods for through casing hydraulic fracture mapping.
  • Hydraulic fracturing has being performed for more than 60 years in more than a million wells. Despite the long history in hydraulic fracturing, the growth of fractures over time is not well understood.
  • high pressure fracturing fluid or pumping fluid is injected to a target geological formation (e.g., a tight shale formation) through a borehole and creates fractures in the target geological formation.
  • Proppants e.g., sand
  • fractures are typically injected with fracturing fluid to keep fractures open.
  • Embodiments of the present disclosure provide induction logging techniques for the electrical investigation of earth formations.
  • the techniques include lowering of an induction logging tool into a borehole at multiple logging depths of the borehole.
  • the techniques further include exciting transmitting coils using a sinusoidal signal at multiple frequencies.
  • the techniques include recording data using multiple receivers on the induction logging tool at different logging depths, and the data so recorded is processed using an inverse algorithm so as to generate a mapping of the earth formations, such as fractures.
  • FIG. la depicts an environment for injection of contrast agents in fractures.
  • FIG. lb is a line diagram to depict interactions of EM waves and received EM responses from fractures.
  • FIG. lc is a block diagram of a logging tool design according to embodiments of the invention.
  • FIG. 2 is a block diagram of the transmitter control of the induction logging tool.
  • FIG. 3 is a block diagram of the receivers control unit of the induction logging tool.
  • FIG. 4 is a block diagram of the bucking control unit of the induction logging tool.
  • FIG. 5 is a line diagram of an induction logging tool according to embodiments of the invention.
  • FIG. 6 is a flow chart describing an induction logging technique according to embodiments of the invention.
  • FIG. 7 is a line diagram depicting an apparatus for experimental validations.
  • FIG. 8 is a graph depicting validations in free space in a cased-hole environment.
  • FIG. 9 is a graph depicting conductivity reconstruction in tap water in a cased- hole environment.
  • FIG. 10 depicts measured data and simulation in tap water in a cased-hole environment.
  • FIG. 11 depicts conductivity reconstruction in salty water in a cased-hole environment.
  • FIG. 12 depicts measured data and simulation in salty water in a cased-hole environment.
  • FIG. lc illustrates a block diagram of an induction logging system 100 according to embodiments of the present disclosure.
  • the induction logging system 100 includes a transmitters control unit 102, a bucking control unit 104, a receivers control unit 106, a reference clock 108, and a central control unit 110.
  • the central control unit 110 may further include a temperature sensor 112 and a data storage 114.
  • the central control unit 110 may be used for system initialization, logging control, and data storage.
  • the central control unit 110 may monitor changes in excitation currents on both transmitters and bucking transmitters. Further, the central control unit 110 may compensate changes if needed and collect measurement data from each receiver by controlling switch arrays.
  • FIG. 2 illustrates a block diagram of an example transmitters control unit 102 according to embodiments of the present disclosure.
  • the transmitters control unit 102 is configured to transmit electric or magnetic signals towards target formations or fractures.
  • the transmitters control unit 102 can drive one or more transmitters 1028.
  • transmitters can be, but are not limited to, small dipoles or magnetic coils oriented in three different axes that can emit electric or magnetic fields in arbitrary orientations.
  • the transmitters control unit 102 can include a sub-processing unit 1024 that is configured to receive and implement commands from the central control unit 110 shown in FIG. lc.
  • the transmitters control unit 102 can further include a waveform amplifier 1022 that is configured to enhance driving power for the transmitter 1028. This may be done so as to increase the incident signal level.
  • the waveform amplifier 1022 can be, but is not limited to, a linear power amplifier.
  • Alinear power amplifier is an electronic circuit whose output is proportional to its input; however, it is capable of delivering more power to a load.
  • the amplitude of the phase currents on transmitter 1028 may be obtained through a transistor Rl 1026.
  • the programmable sine wave generator 1020 is connected to the reference clock 108.
  • the programmable sine wave generator 1020 is configured to compensate the fluctuation in currents due to changes in ambient temperature. Therefore, excitation currents on the transmitter 1028 remain the same during logging.
  • FIG. 3 illustrates a block diagram of an example receivers control unit 106 of the induction logging tool in accordance with embodiments of the present disclosure.
  • the receivers control unit 106 can include multiple receivers 1068a... 1068n.
  • the multiple receivers 1068a... 1068n are configured to detect weak signals propagating back from the target formation. Further, the multiple receivers 1068a... 1068n are made with high sensitivity.
  • the multiple receivers 1068a... 1068n are followed by corresponding linking pre-amplifiers 10602a... 10602 ⁇ .
  • the pre-amplifiers 10602a... 10602 ⁇ are configured for low noise amplification, driving power capability enhancement, and common-mode interference rejection.
  • the receivers control unit 106 further includes a switch array 1066, which is configured for selecting signals from the multiple receivers 1068a... 1068n.
  • the switch array 1066 is in further communication with an amplifier and band pass filter 1064.
  • the amplifier and band pass filter 1064 may be configured to receive the selected signals from the switch array 1066 and further enhance and filter the signals thus received.
  • the amplifier and band pass filter 1064 increase the signal-to-noise ratio of the selected pre-amplified signal.
  • the useful weak signals selected from strong noise by using a lock-in amplifier 1060.
  • the lock-in amplifier 1060 is also in communication with the reference clock 108.
  • the receivers control unit 106 further includes a sub-processing unit 1062 which is in communication with the lock-in amplifier 1060 to receive the amplitude and phase of the signals processed by the lock-in amplifier 1060. This data can be then uploaded to the central control unit 110. Further, during measurement process, the sub-processing unit 1062 is configured to control the switch array 1066.
  • FIG. 4 illustrates a block diagram of an example bucking control unit 104 according to embodiments of the present disclosure.
  • bucking may be needed.
  • the bucking control unit 104 may include multiple bucking transmitters 10402a... 10420 ⁇ .
  • the bucking control unit 104 may also include a switch array 1048, a waveform amplifier 1042, a programmable sine wave generator 1040, a sub-processing unit 1044, and a current detection resistor R2 1046.
  • the sub- processing unit 1044 which is in communication with the central control unit 110, may take commands from the central control unit 110.
  • the bucking control unit 104 further includes a waveform amplifier 1042 that is configured to enhance driving power for the bucking transmitters 10402a... 10402 ⁇ . This is done so as to increase the incident signal level.
  • the waveform amplifier 1042 can be, but is not limited to, a linear power amplifier.
  • a linear power amplifier is an electronic circuit whose output is proportional to its input; however, it is capable of delivering more power to a load.
  • the amplitude of the phase currents on bucking transmitters 10402a... 10402 ⁇ may be obtained through the current detection resistor R2 1046.
  • the programmable sine wave generator 1040 is connected to the reference clock 108.
  • the programmable sine wave generator 1040 is configured to compensate the fluctuation in currents due to changes in ambient temperature. Therefore, excitation currents on the bucking transmitters 10402a... 10402 ⁇ remain the same during logging.
  • This bucking technique implementation may be implemented readily, because it applies the active bucking technique that allows the magnitude and phase of the bucking transmitter to be adjusted individually to optimize the nulling effect.
  • This active bucking technique can also achieve minimum effects on secondary fields from fractures. Therefore, secondary fields received at receivers with bucking may be the same as secondary fields received at receivers without bucking transmitters.
  • FIG. 5 illustrates a line diagram of an example induction logging tool according to embodiments of the present disclosure.
  • the induction logging tool may include an elongated cylindrical body including a transmitting coil set 202.
  • the transmitting coil set may include multiple coils with different orientation.
  • the orientation of the transmitting coils 202 may be in three different axes, i.e., each in axis u, axis v, and axis w.
  • the induction logging tool may include a bucking coil set 204, which may also be configured with orientation of three coils in three different axes.
  • a receiving coil set 206 is also included in the induction logging tool 100.
  • the receiving coil may be a three coil set with the three coils having orientation in different axes, namely u, v, and w.
  • transmitters and receivers are placed in three orthogonal orientations.
  • the orientations can be denoted as u, v, and w.
  • E uv is the electric field transmitted by a transmitter oriented in u direction and received by a receiver oriented in v direction.
  • FIG. 6 is a flow chart depicting an example induction logging technique 600 according to embodiments of the present disclosure.
  • the technique 600 may begin at step 602 wherein the induction logging tool 100 is lowered into a borehole for mapping of fractures.
  • the borehole may be filled with borehole fluid or oil-based mud. These materials form a homogeneous background with weak or zero conductivity.
  • the borehole may be vertical to the ground (vertical borehole), deviated, or parallel to the ground (horizontal borehole). Outside of the borehole, there can be a metallic or fiberglass casing or casing made with other material that can support the near borehole structure.
  • the casing has a certain thickness that ranges from a few millimeters to several centimeters.
  • the metallic casing may have high conductivity and/or a certain level of magnetic permeability.
  • a couple inches of cement layer may be placed outside of the casing.
  • the depth of the induction logging tool 100 is determined. If the induction logging tool 100 has reached a pre-assigned logging depth, the technique 600 proceeds to step 612 wherein the data captured is processed using an inverse algorithm. However, if the induction logging tool 100 has not reached a pre-assigned logging depth at step 606, the transmitter coils 202 are excited.
  • the transmitter coils 202 may be excited by a sinusoidal signal at one or multiple given frequencies between about 10 Hz and about 100 Hz. Transmitters with orientations of u, v, and w may be excited simultaneously or in a sequence.
  • the corresponding bucking coils 204 are excited and data are collected using the receiver coils 206.
  • the induction logging tool 100 is moved on to next position for data collection. This data is then processed at step 612 using the inverse algorithm. The data processed by the inverse algorithm at step 612 is outputted at step 614 as fracture mapping.
  • EM fields received by the receivers 11068a... 1068n can be denoted as the total electric field, E t , or the total magnetic field, H t .
  • Total fields can be considered a sum of incident fields (E H l ) and scattered fields (E s , H s ).
  • Incident fields are the electric and magnetic fields that propagate into the formations without the existence of fractures.
  • Scattered fields are the results of interactions between incident fields and fractures. Therefore, the following equations result:
  • volume equivalent theorem scattered fields can be viewed as radiated fields from equivalent volume sources.
  • the equivalent sources are related to total fields and contrasts of fractures.
  • total fields received by receivers on a logging tool can be described by
  • ⁇ is the angle frequency
  • e b and ⁇ ⁇ are background permittivity and magnetic permeability
  • k b is the background wave number.
  • a and F are vector potentials that may be calculated by
  • D and B are electric and magnetic flux densities, respectively, e r and ⁇ ⁇ are effective permittivity and magnetic permeability of fractures, respectively, and g is the scalar Green's functions in homogeneous background.
  • ⁇ ⁇ and ⁇ ⁇ are dielectric and magnetic contrasts, respectively.
  • equations (3) and (4) are functions of contrasts and fractures characteristics. They can be rewritten as
  • the above equations may be solved by using multiple methods.
  • the methods can be either an iterative method, distorted born approximation method, numerical mode matching, or a BCGS- FFT method or its improved version the mixed-order BCGS-FFT method.
  • FIG. 7 depicts an apparatus 700 for experimental validation of the method 600.
  • the scale factor for this system is 1 : 1000 in frequency and 40: 1 in conductivity and thus 1 :200 in dimensions.
  • the whole experiment is done under water inside a water tank 704.
  • Water filled in the water tank 704 has a weak conductivity that simulates target formation environment.
  • a waterproof metallic casing 706 is set up in the water tank. This metallic casing is 78 ⁇ in thickness and has an electric conductivity of 5.96xl0 7 S/m.
  • An induction logging tool 710 working at 100 kHz is made. It can move freely in air inside the metallic casing suspended in the water tank 702 through a linear motor 702.
  • Athin layer of high conductivity material 708 is placed inside the water tank 704 to simulate the response of a contrast-enhanced fracture.
  • the forward modeling algorithm is validated by comparing secondary fields received in logging tool while logging in air with the existence of one fracture. The comparison is shown in FIG. 8. The logging curves from different receivers are shown. Excellent agreement is indicated in this comparison.
  • the water tank 704 is filled with tap water that has a conductivity of 0.0293 S/m.
  • the electric conductivity mapping result obtained from logging data is shown in FIG. 9.
  • a fracture can be easily identified and its conductivity is clearly shown. This fracture is successfully mapped with the correct electric conductivity value.
  • Receiving signals are estimated using the reconstructed fracture. The comparison of these estimated receiving signals and measured signals (logging data) is shown in Figure 10. Again, excellent agreement can be observed.
  • the second experiment is done in the water tank 704 filled with salty water.
  • the salty water has higher conductivity at 1.02 S/m.
  • the fracture is correctly mapped in salty water background.
  • the comparison of estimated receiving signal and measured data shown in FIG. 12 also indicates an excellent agreement.
  • each block in the flowchart or block diagrams may represent a module, segment, or portion of instructions, which comprises one or more executable instructions for implementing the specified logical function(s).
  • the functions noted in the block may occur out of the order noted in the figures.
  • two blocks shown in succession may, in fact, be executed substantially concurrently, or the blocks may sometimes be executed in the reverse order, depending upon the functionality involved.

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  • Physics & Mathematics (AREA)
  • Engineering & Computer Science (AREA)
  • Remote Sensing (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Electromagnetism (AREA)
  • Environmental & Geological Engineering (AREA)
  • Geology (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • General Physics & Mathematics (AREA)
  • Geophysics (AREA)
  • Geophysics And Detection Of Objects (AREA)

Abstract

La présente invention porte sur des systèmes et des procédés de cartographie de fractures hydrauliques à travers tubage. Selon un aspect, la présente invention porte sur un outil de diagraphie par induction pour cartographier les fractures de la terre, qui comprend un ensemble de bobines d'émission, un ensemble de bobines de compensation d'émission, et un ensemble de bobines de réception. L'outil de diagraphie par induction peut être abaissé dans un trou de forage à des profondeurs multiples. Divers enregistrements des signaux électriques et magnétiques peuvent être capturés à l'aide de l'ensemble des bobines de réception. Ces données peuvent ensuite être traitées à l'aide d'un algorithme inverse pour fournir une cartographie des fractures de la terre.
PCT/US2016/017015 2015-04-15 2016-02-08 Cartographie de fractures hydrauliques à travers tubage WO2016167860A1 (fr)

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US201562147745P 2015-04-15 2015-04-15
US62/147,745 2015-04-15

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WO2016167860A1 true WO2016167860A1 (fr) 2016-10-20

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Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10870793B2 (en) 2013-01-04 2020-12-22 Carbo Ceramics, Inc. Electrically conductive proppant and methods for energizing and detecting same in a single wellbore

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6147496A (en) * 1996-07-01 2000-11-14 Shell Oil Company Determining electrical conductivity of a laminated earth formation using induction logging
US6618676B2 (en) * 2001-03-01 2003-09-09 Baker Hughes Incorporated Efficient and accurate pseudo 2-D inversion scheme for multicomponent induction log data
WO2005062076A1 (fr) * 2003-12-03 2005-07-07 Baker Hughes Incorporated Procede et appareil pour l'utilisation de la composante reelle d'un champ magnetique des mesures de resistivite a multiples composantes
RU2466431C1 (ru) * 2011-04-05 2012-11-10 Общество с ограниченной ответственностью Научно-производственная фирма "ВНИИГИС - Забойные телеметрические комплексы" (ООО НПФ "ВНИИГИС - ЗТК") Способ индукционного каротажа скважин в процессе бурения
RU2506611C2 (ru) * 2010-08-24 2014-02-10 Николай Викторович Беляков Прибор электромагнитного каротажа в процессе бурения

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6147496A (en) * 1996-07-01 2000-11-14 Shell Oil Company Determining electrical conductivity of a laminated earth formation using induction logging
US6618676B2 (en) * 2001-03-01 2003-09-09 Baker Hughes Incorporated Efficient and accurate pseudo 2-D inversion scheme for multicomponent induction log data
WO2005062076A1 (fr) * 2003-12-03 2005-07-07 Baker Hughes Incorporated Procede et appareil pour l'utilisation de la composante reelle d'un champ magnetique des mesures de resistivite a multiples composantes
RU2506611C2 (ru) * 2010-08-24 2014-02-10 Николай Викторович Беляков Прибор электромагнитного каротажа в процессе бурения
RU2466431C1 (ru) * 2011-04-05 2012-11-10 Общество с ограниченной ответственностью Научно-производственная фирма "ВНИИГИС - Забойные телеметрические комплексы" (ООО НПФ "ВНИИГИС - ЗТК") Способ индукционного каротажа скважин в процессе бурения

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Title
DMITRIEV A.YU.: "Osnovy technologii bureniya skvazhin. Uchebnoe posobie.", PETROLEUM LEARNING CENTRE. IZDATELSTVO TOMSKOGO POLITEKHNICHESKOGO UNIVERSITETA., 2008, pages 22 - 27 , 91-92, 96-98 *

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10870793B2 (en) 2013-01-04 2020-12-22 Carbo Ceramics, Inc. Electrically conductive proppant and methods for energizing and detecting same in a single wellbore

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