WO2014106006A1 - Procédé de contrôle de fluide d'injection - Google Patents

Procédé de contrôle de fluide d'injection Download PDF

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Publication number
WO2014106006A1
WO2014106006A1 PCT/US2013/077916 US2013077916W WO2014106006A1 WO 2014106006 A1 WO2014106006 A1 WO 2014106006A1 US 2013077916 W US2013077916 W US 2013077916W WO 2014106006 A1 WO2014106006 A1 WO 2014106006A1
Authority
WO
WIPO (PCT)
Prior art keywords
borehole
monitoring
monitoring system
injection
disposing
Prior art date
Application number
PCT/US2013/077916
Other languages
English (en)
Inventor
Sushant M. Dutta
Daniel T. Georgi
Randy Gold
Arcady Reiderman
Original Assignee
Baker Hughes Incorporated
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Baker Hughes Incorporated filed Critical Baker Hughes Incorporated
Publication of WO2014106006A1 publication Critical patent/WO2014106006A1/fr

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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
    • E21B47/10—Locating fluid leaks, intrusions or movements
    • E21B47/113—Locating fluid leaks, intrusions or movements using electrical indications; using light radiations
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH 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
    • E21B47/13—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. radio frequency

Definitions

  • injection wells are used for various purposes in the drilling industry.
  • injection fluid e.g., water, C0 2
  • a producing well producing oil, for example
  • Prior systems to monitor injection fluid have been disposed in the production well or one or more monitor wells (separate from the production well and injection well) or some combination thereof.
  • the systems obtain resistivity or conductivity (inversely proportional to resistivity) measurements around the borehole in which they are located and can determine the boundary between materials that have discernibly different resistivity values (e.g., the boundary between a production fluid like oil and an injection fluid like water).
  • resistivity or conductivity inversely proportional to resistivity
  • Prior methods of monitoring are also problematic because the injected fluid may not necessarily reach the production well due to heterogeneity and/or permeability anisotropy around the injection well. In this case, the direction and flow rate from the injection well is unknown.
  • Another exemplary purpose of an injection well is for the introduction of material into an underground storage reservoir. In this case, the seal on the storage reservoir must be monitored to ensure that the stored material is not leaking into the surrounding area.
  • a method of monitoring an injection substance injected into an injection well penetrating the earth includes disposing a monitoring system in a borehole, both a transmitting and a receiving portion of the monitoring system being disposed in the borehole; injecting the injection substance into the injection well; and monitoring, using a processor processing the received signal, flow of the injection substance out of the injection well.
  • a method of monitoring an underground reservoir storing a substance introduced through an injection well includes disposing a monitoring system in a borehole, both a transmitting portion and a receiving portion of the monitoring system being disposed in the borehole; injecting the injection substance into the injection well for storage in the underground reservoir; and monitoring, using a processor processing the received signal, boundary conditions surrounding the underground reservoir.
  • FIG. 1 illustrates a cross-sectional view of an injection substance monitoring system according to an embodiment of the invention
  • FIG. 2 illustrates a cross-sectional view of an injection substance monitoring system according to another embodiment of the invention
  • FIG. 3 depicts the monitoring system in the injection well according to an embodiment of the invention
  • FIG. 4 depicts the monitoring system in the injection well and a monitor well according to an embodiment of the invention
  • FIG. 5 depicts the monitoring system in the injection well and a monitor well according to another embodiment of the invention
  • FIG. 6 depicts the monitoring system according to an embodiment of the invention
  • FIG. 7 illustrates a cross-sectional view of a monitoring system according to an embodiment of the invention
  • FIG. 8 illustrates a cross-sectional view of an injection substance monitoring system according to an embodiment of the invention.
  • FIG. 9 is a flow diagram of a method of monitoring an injection fluid according to an embodiment of the invention.
  • An exemplary injection arrangement positions a number of injection wells surrounding the production well.
  • the injections wells may even be essentially equidistant from the production well, and each injector may even inject the injection fluid at the same rate.
  • inhomogeneity in the reservoir may render the injection system inhomogeneous (injection fluid from each injection well reaches the production well at a different time or not at all).
  • the injection fluid front from a given injection well may be advancing toward the production well faster than the injection fluid front from any of the other wells.
  • the given injection well may be choked off to increase the time until an injection fluid front reaches (and contaminates) the production well.
  • a monitoring system in the production well would not be capable of making such a determination in time to prolong the production. This is because the system in the production well would only identify the injection fluid front when it has already approached the production well. Also, if one of the other injection wells' injection fluid had been misdirected away from the production well due to the permeability anisotropy around that injection well, the production well would not detect that fluid front over a length of time but would not provide any information about the directivity of that injection fluid.
  • Embodiments detailed herein describe a method of monitoring boundary conditions from the injection well itself. By detecting the boundary between the material injected through the injection well and surrounding material, the fluid front advancing toward a production well (or in an unintended direction other than the direction of the production well) or material injected into a storage reservoir may be effectively monitored during its travel into the reservoir and throughout the useful life of the reservoir.
  • FIG. 1 illustrates a cross-sectional view of an injection substance 101 monitoring system 130 according to an embodiment of the invention. While any system that resides within a single injection well and monitors boundary conditions from that injection well may be used, a transient electromagnetic (EM) system including a transmitter 110 and one or more receivers 120 pair in the injection well 100 is discussed as an exemplary monitoring system 130 in the embodiment discussed with reference to FIG. 1 and is detailed with reference to FIG. 2.
  • the production well 150 is shown as another borehole penetrating the earth 160 in an area including a formation 165, which represents any subsurface material of interest in the production.
  • a computer processing system 140 may process the data obtained by the monitoring system 130.
  • FIG. 2 illustrates a cross-sectional view of an injection substance 101 monitoring system 130 according to another embodiment of the invention.
  • FIG. 2 shows a horizontal production well 150 and a horizontal injection well 100. All of the embodiments of the monitoring system 130 discussed herein apply to both vertical wells (see e.g., FIG. 1) and horizontal wells.
  • FIG. 3 depicts the monitoring system 130 in the injection well 100 according to an embodiment of the invention.
  • the exemplary transient EM monitoring system 130 is one embodiment of a system that may be used, but any system that facilitates the monitoring of fluid boundary dynamics from the injection well 100 may be used to implement embodiments of the method and system described herein.
  • a continuous- wave system rather than a transient EM system may be used as the monitoring system 130.
  • the transmitter 110 may be a three component transmitter with antennas oriented in the z, x, and y directions.
  • An array of receivers 120a-120n may be disposed in the injection well 100.
  • Each of the receivers 120 may be a three component receiver with antennas oriented in the x, y, and z directions.
  • the transmitter 110 and one or more receivers 120 may be moved along the length of the injection well 100 and may provide information as a function of depth. In other embodiments, the transmitter 110 and one or more receivers 120 may be affixed to a particular position within the injection well 100.
  • FIG. 4 depicts the monitoring system 130 in the injection well 100 and a monitor well 410 according to an embodiment of the invention. According to the alternate embodiment shown in FIG. 4, some of the array of receivers 120b-120n, are disposed in a monitor well 410 while the transmitter 110 and one receiver 120a (or more) are disposed in the injection well 100.
  • FIG. 5 depicts the monitoring system 130 in the injection well 100 and a monitor well 510 according to another embodiment of the invention.
  • one or more receivers 120 may be in a monitor well 510 while the transmitter 110 is disposed in the injection well 100.
  • this separation of the transmitter 110 and one or more receivers 120 is possible when synchronization of the transmitter 110 and receiver(s) 120 is included.
  • the synchronization (to within a few microseconds) may be achieved, for example, via hardwire or fiber optic connection between the transmitter 110 and receiver(s) 120.
  • wireless synchronization of the transmitter 110 and receiver(s) 120 may be performed.
  • the exemplary transient EM monitoring system 130 addresses two concerns. First, transient (time-domain) measurements relative to continuous-wave measurements provide improved spatial resolution. Second, signal-to-noise ratio is improved by increasing the strength of the transmitter and receiver magnetic dipoles.
  • the transmitter 110 and receiver 120 of the present embodiment are designed to generate a relatively large switchable dipole (e.g., dipole moment of 1 kAm 2 ) with power consumption that is more than a hundred times less than with a conventional long-coil.
  • the monitoring system 130 measures conductivity. The monitoring system 130 operates by altering the transmitted electromagnetic (EM) field to produce a transient EM signal.
  • the receiver 120 receives a signal based on the transient EM signal transmitted by the transmitter 110. This received signal represents the conductivity of the surrounding material.
  • the fluid front of the injection substance 101 may be detected and its directivity and speed may be monitored.
  • the directivity of the injection substance 101 is based on the permeability anisotropy around the injection well 100. That is, the injection substance 101 will not flow in all directions uniformly from the injection well 100 and, as noted above, may not reach a targeted production well 150 at all within a given period of time.
  • the permeability anisotropy around the injection well 100 may be determined. Because the exemplary monitoring system 130 (transient EM) measures conductivity, an injection substance 101 that has a lower conductivity than that of
  • FIG. 6 depicts the monitoring system 130 according to an embodiment of the invention.
  • the transient EM monitoring system 130 is again used as an example.
  • the borehole 330 e.g., injection well 100 or monitor borehole 410, FIG. 4 810, FIG.
  • a magnetically permeable or ferrite material 620 surrounds the casing 610.
  • the lower impedance path created by the magnetically permeable or ferrite material 620 reduces the magnetic flux through the casing 610.
  • the transient EM monitoring system 130 is mounted outside the casing 610 and outside the magnetically permeable or ferrite material 620.
  • FIG. 7 illustrates a cross-sectional view of a monitoring system 130 according to an embodiment of the invention.
  • an injection substance 101 is injected into the injection well 100 for storage in an underground reservoir 710.
  • the injection substance 101 may be carbon dioxide, waste water, or natural gas, for example.
  • the monitoring system 130 the fluid front of the injection substance 101 into the reservoir 710 as well as any leak from the reservoir 710 may be monitored.
  • FIG. 8 illustrates a cross-sectional view of an injection substance 101 monitoring system 130 according to an embodiment of the invention.
  • the monitoring system 130 according to the present embodiment resides in a monitor borehole 810 in proximity to the injection well 100.
  • the distance D from the injection well 100 to the production well 150 is 100 feet
  • the distance d from the injection well 100 to the monitor borehole 810 may be approximately 5 to approximately 10 feet.
  • the monitor borehole 810 includes the monitoring system 130 to monitor the injection substance 101 from the injection well 100 (rather than a fluid front approaching the production well 150) and because the monitor borehole 810 is proximate to the injection well 100, a single monitor borehole 810 is sufficient though two or more monitor boreholes 810 may be used.
  • FIG. 9 is a flow diagram of a method 900 of monitoring an injection substance according to an embodiment of the invention.
  • the method 900 uses the transient EM monitoring system 130 described with reference to FIG. 2.
  • the method 900 includes inserting a monitoring system 130 transmitter 110 and one or more receivers 120 into the injection well 100 (block 910).
  • the method 900 includes injecting the injection substance 101 into the injection well 100.
  • the method 900 includes altering the transmitted EM field to produce a transient EM signal out of the injection well 100.
  • receiving a received signal based on the transient EM signal facilitates determining conductivity.
  • Monitoring the injection substance 101 based on the received signal (block 950) includes monitoring the fluid front based on a difference in conductivity between the injection substance 101 and the
  • This monitoring may include the use of time-lapse measurements to determine the motion of the injection fluid front.
  • This monitoring may include monitoring injection fluid directed to a production well 150 to increase production.
  • the monitoring may also include monitoring a substance injected into an underground reservoir 710 (FIG. 7).

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  • Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Geophysics (AREA)
  • Remote Sensing (AREA)
  • Electromagnetism (AREA)
  • Geophysics And Detection Of Objects (AREA)

Abstract

L'invention porte sur un procédé de contrôle d'une substance d'injection injectée dans un puits d'injection pénétrant dans la terre et sur un procédé de contrôle d'un réservoir souterrain stockant une substance introduite à travers un puits d'injection. Les procédés mettent en œuvre la disposition d'un système de contrôle dans un trou de forage, une partie d'émission et une première partie de réception du système de contrôle étant toutes deux disposées dans le trou de forage. Le procédé de contrôle d'une substance d'injection met également en œuvre l'injection de la substance d'injection dans le puits d'injection, et le contrôle, à l'aide d'un processeur traitant le signal reçu, d'un écoulement de la substance d'injection hors du puits d'injection. Le procédé de contrôle d'un réservoir souterrain met en œuvre l'injection de la substance d'injection dans le puits d'injection pour un stockage dans le réservoir souterrain, et le contrôle, à l'aide d'un processeur traitant le signal reçu, de conditions de limite entourant le réservoir souterrain.
PCT/US2013/077916 2012-12-27 2013-12-27 Procédé de contrôle de fluide d'injection WO2014106006A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201261746180P 2012-12-27 2012-12-27
US61/746,180 2012-12-27

Publications (1)

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WO2014106006A1 true WO2014106006A1 (fr) 2014-07-03

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US (1) US20140182842A1 (fr)
WO (1) WO2014106006A1 (fr)

Cited By (1)

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CN108571312A (zh) * 2018-03-21 2018-09-25 中国石油天然气股份有限公司 油田分层开采用井下无线对接测调工具

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CN104747146A (zh) * 2015-02-15 2015-07-01 中国石油天然气股份有限公司 一种油田注水井的分层注水测调方法以及系统
US10126448B2 (en) 2016-04-20 2018-11-13 Baker Hughes Oilfield Operations Llc Formation measurements using downhole noise sources
CN105863584B (zh) * 2016-04-27 2018-11-27 于世江 一种智能无线配水系统
CN105756635B (zh) * 2016-04-27 2019-02-19 于世江 一种注水井智能无线配水装置

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US5151658A (en) * 1989-12-29 1992-09-29 Chinetsu Gijutsu Kaihatsu Kabushiki Kaisha Three-dimensional detection system for detecting fractures and their distributions in the earth crust utilizing an artificial magnetic field and magnetic particle tracer
US20100243241A1 (en) * 2009-03-25 2010-09-30 Occidental Chemical Corporation Detecting Fluids In a Wellbore
US20100282460A1 (en) * 2009-05-05 2010-11-11 Stone Matthew T Converting Organic Matter From A Subterranean Formation Into Producible Hydrocarbons By Controlling Production Operations Based On Availability Of One Or More Production Resources
US20110309835A1 (en) * 2010-06-17 2011-12-22 Barber Thomas D Method for determining spatial distribution of fluid injected into subsurface rock formations
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Patent Citations (5)

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US5151658A (en) * 1989-12-29 1992-09-29 Chinetsu Gijutsu Kaihatsu Kabushiki Kaisha Three-dimensional detection system for detecting fractures and their distributions in the earth crust utilizing an artificial magnetic field and magnetic particle tracer
US20120306501A1 (en) * 2008-01-08 2012-12-06 William Marsh Rice University Methods for magnetic imaging of geological structures
US20100243241A1 (en) * 2009-03-25 2010-09-30 Occidental Chemical Corporation Detecting Fluids In a Wellbore
US20100282460A1 (en) * 2009-05-05 2010-11-11 Stone Matthew T Converting Organic Matter From A Subterranean Formation Into Producible Hydrocarbons By Controlling Production Operations Based On Availability Of One Or More Production Resources
US20110309835A1 (en) * 2010-06-17 2011-12-22 Barber Thomas D Method for determining spatial distribution of fluid injected into subsurface rock formations

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN108571312A (zh) * 2018-03-21 2018-09-25 中国石油天然气股份有限公司 油田分层开采用井下无线对接测调工具

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