US3776032A - Method and apparatus for detecting an inflow of fluid into a well - Google Patents

Method and apparatus for detecting an inflow of fluid into a well Download PDF

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Publication number
US3776032A
US3776032A US00268369A US3776032DA US3776032A US 3776032 A US3776032 A US 3776032A US 00268369 A US00268369 A US 00268369A US 3776032D A US3776032D A US 3776032DA US 3776032 A US3776032 A US 3776032A
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Prior art keywords
well
fluid
signal
drilling
inflow
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US00268369A
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English (en)
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C Vogel
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Shell USA Inc
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Shell Oil Co
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    • 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
    • E21B47/107—Locating fluid leaks, intrusions or movements using acoustic means
    • 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

Definitions

  • the present invention relates to a method and apparatus for detecting an inflow of either gas or liquid into a well during the drilling of the well.
  • the invention is particularly adapted for use with rotary drilling equipment.
  • a drill bit is attached to the end of a tubular drill string and extends into the well.
  • the drill string is rotated by surface equipment while liquid, commonly referred to as drilling mud, is circulated through the tubular string, out of the drill bit and returns to the surface through the annulus between the drill string and the borehole wall.
  • the drilling mud is circulated both to cool the drill bit and bring the drill bit cuttings to the surface.
  • a blowout normally occurs when the formation pressure exceeds the hydrostatic head generated byv the column of drilling mud in the borehole.
  • the hydrostatic head of the drilling mud can be seriously reduced by the gradual inflow of either gas or liquids, particularly salt water, into the well.
  • these fluids flow into the well they reduce the specific gravity of the drilling fluid which is normally measured in pounds per gallon and referred to as ppg.
  • ppg pounds per gallon
  • the present invention solves the above problems by providing unique method and apparatus for sensing the inflow of fluids into the well. More particularly, the method and apparatus will sense the inflow of either gas or liquids into the well bore during the actual drilling of the well.
  • the exact apparatus described is par ticularly adapted for use with a transmission system using pressure mud pulses to transmit the information, although it could be modified for use with an electrical transmission circuit.
  • the apparatus comprises a pair of acoustical transducers which are energized at a relatively high frequency.
  • One of the transducers is disposed to transmit pressure waves through the drilling mud before it is circulated to the drill bit.
  • the second transducer is disposed to transmit pressure waves through the drilling mud after it is circulated through the drill bit and is returning to the surface through the annular space between the drill string and the borehole.
  • the transducers generate signals that are related to the received scattered and reflected acoustical energy, the signals compared, and the difference between the signals transmitted to the surface.
  • the signals from the two transducers will be substantially equal and no difference in signal will occur. It has been discovered that only a small quantity of gas, for example 1 percent by volume, will cause a distinct difference in the two transducer signals. This difference can then be converted to a signal which is transmitted to the surface by means of mud pulses.
  • an electrode for measuring the resistivity of the drilling mud.
  • the resistivity of the drilling mud will remain relatively constant, unless there is an inflow of fuid into the well.
  • the inflow of fluid can be either salt water or crude oil.
  • the signal transmitting system comprises three separate pulse generating circuits having different frequen-. cies.
  • select-a frequency indicating no inflow of fluids into the well a second frequency indicating the inflow of gas into the: well, and the third frequency to indicate the inflow of liquids, either crude oil or salt water, into the well;
  • the apparatus could be extended so that it is possible to include information indicating that both gas and liquids are flowing into the well. Normally, this is not required since the information that there isan inflow into the well is sufficient to alert. the drilling personnel that steps must be taken to control the well before a serious blowout occurs.
  • FIG. 1 is an elevation view of a drill string in a well incorporating apparatus of the present invention
  • FIG. 2 is a schematic circuit of the apparatus shown in block diagram form.
  • FIG. 1 there is shown the present invention installed in the drill string disposed in a bore hole 10. More particularly, the invention is installed in an instrument sub 13 which is attached to the drill string 11 at its upper end and has a rotary drill bit 12 disposed at its lower end.
  • drilling mud or fluid is circulated down the center of the drill string or stem 10 through the passageway formed in the instrument sub and out the center of the rotary bit 12.
  • the drilling mud then returns to the surface through the annular space between the outer surface of the drill string and instrument sub and wall of the borehole 10.
  • the drilling mud serves both to cool and lubricate the drill bit 12, as well as to carry the drill cuttings back to the surface.
  • the drilling mud is weighted with various materials so that the hydrostatic head generated by the column of drilling mud in the borehole is sufficient to hold back the anticipated pressures of the formations penetrated by the borehole.
  • a mud turbine 14 which drives a generator 15.
  • a bellows-type pressure compensatingequalization system 16 is provided so that the pressure within the generator is maintained slightly above the pressure in the mud system so that any leakage will be from the generator out instead of from the mud system into the generator.
  • the circuits required for powering the resistivity logging portion of the system are disposed in an instrument package 20 which is mounted in a passageway 33 formed in the wall of the instrument sub.
  • the instrument package 21 used for powering and controlling the acoustical transducers 32 and 31 is mounted in a similar passageway 34 disposed above the passageway 33.
  • the electrode 31 of the resistivity sensor is disposed in a horizontal passageway which intersects the passageway 33.
  • the acoustic transducers 31 and 32 are disposed in the horizontal passageway which also intersects the passageway 33.
  • the data sensed by the resistivity and gas detectors is transmitted to the surface by means of pressure pulses produced in the circulating mud system.
  • the pressure pulses are produced in the circulating mud system by means of a valve which effectively chokes the passageway through the center of the instrument sub.
  • the valve comprises a piston 22 disposed for axial movement and having a central bore for passage of the mud stream and a valve 23 having a bore which may be either aligned with the bore in the 22 piston or to close the bore through the 22 piston.
  • the valve 23 is positioned by means of a solenoid 24 which is actuated to produce a predetermined number of pulses in the mud stream to signify a certain condition.
  • the piston is moved to an upper position by means of a compression spring 25 which forces the piston and valve assembly up against a stop 26 formed on the inner surface of the instrument sub.
  • the compression spring 25 rests at its lower end against a horizontal plate 27 formed in the inner wall of the instrument sub.
  • the plate 27 also has suitable openings so that the mud may flow through the openings.
  • An inclined surface 28 is formed on the inner surface of the instrument sub and is used for resetting the valve 23. More particularly, the pulse system operates by the solenoid first moving the valve 23 to a position where iteffectively chokes off the central bore through the piston 22. The circulating mud will then force the piston downwardly until the valve 23 strikes the inclined surface 28 which will force the valve to the left.
  • the frequency of the pressure pulses can be controlled to signify the condition being measured by the electrode 30 or the acoustic transducers 31 and 32.
  • suitable passageways are provided around the exterior of the piston 22 to provide a sufficient flow of drilling mud.
  • FIG. 2 there is shown in block diagram form the circuits required for operating the valve to generate the pressure pulses in response to the measurements made by the acoustic transducers and the resistance measuring electrode.
  • a pulse generator is coupled to the acoustic transducers 31 and 32 through diodes 51 and 52. Also coupled to the transducers are suitable inductances 58 and 59 designed to cause the transducers to resonate.
  • the pulse generator 50 should generate a 5 volt pulse of approximately 5 MH.
  • the two transducers are disposed so that the transducer 31 produces acoustic waves in the drilling mud circulating through the center of the instrument package sub while the transducer 32 produces acoustic waves in the drilling mud after it is passed through the drill bit and is returning to the surface through the annular space surrounding the drill string.
  • the transducer 31 produces a reference signal related to the drilling mud without fluid intrusion.
  • the reference transducer 31 one could also substitute a fixed signal.
  • the two transducers are coupled to two analog gates and 56 through the amplifiers 53 and 54, respectively.
  • the two gates 55 and 56 are opened and armed by a gate resonator 57 which is also coupled to the pulse generator 50.
  • the gate generator 57 should produce a pulse for arming the two gates a certain delay period after the production of the pulse which energizes the acoustic transducers. For example, a pulse with a delay period of 7.5 microseconds and a width of approximately two microseconds will operate satisfactorily.
  • the two gates, 55 and 56 will transmit the acoustic signal that is reflected and scattered from the drilling mud back to the two transducers 31 and 32. This signal will be converted to a related electrical signal by the transducers which can be then amplified and passed through the gates.
  • the two gates are coupled to a differential applifier 60 which produces an output signal related to the difference between the two transducer signals.
  • the two transducer signals will be substantially the same and thus the amplifier 60 will produce a zero output signal.
  • a reference signal is used in place of reference transducer 31, that portion of the circuit associated with transducer 31 may be eliminated and the signal in the form of a voltage applied directly to the difi'erential amplifier 60.
  • the differential amplifier is coupled to a trigger and latching circuit 61 which triggers at a certain voltage level to provide an output signal having amplitude and duration sufficient to operate the binary selector switch 62.
  • a conventional Schmidt trigger circuit may be used for the circuit 61.
  • the system is provided with three pulse generators, 63, 64 and 66, which produce 6, 3 and 1.5 pulses per minute.
  • the binary selector switch 62 is designed so that it will transmit the 6 pulse per minute signal in the absence of any signal from the trigger and latching circuit 61. Thus the absenceof any inflow of material into the well will be signaled by the production of six pulses per minute.
  • the binary selector switch When a signal is received from the trigger andlatching circuit 61, the binary selector switch will be moved to the opposite position from that shown and three pulses per minute will be transmitted to the remainder of the circuit.
  • the ouput of the binary selector switch 62 is connected to one position of a second selector switch 65. In its normal position the switch 65 will transmit the signal received from the binary switch 62 to the remainder of the circuit. If there is only a flow of gas or liquid into the well, it will affect primarily the acoustic transducer 32 and three pulses per minute will be transmitted to the remainder of the circuit.
  • the binary selector switch 65 is controlled by the resistivity sensing electrode 30.
  • the resistivity electrode is coupled to one side of a volt AC power supply through a large current limiting resistor 69 while the other side of the power supply is grounded.
  • the voltage at the resistivity electrode is thus related to the conductivity of thefluid between it and ground.
  • Theresistivity electrode may comprise a 1/ 16 inch diameter electrode surrounded by a A inch O.D. insulator, both mounted flush with the outer wall of the drill collar.
  • the electrode 30 is coupled to an amplifier 70 whose input is coupled to ground.
  • the amplifier 70 is coupled to a comparing circuit 71 which is also supplied with a reference voltage indicated as a set point 72.
  • the comparing circuit thus compares a measured resisitivity with a predetermined value and supplies the difference as a signal to the binary switch 65.
  • the set point for the comparing circuit should be set at the approximate value of the resistivity of the drilling mud so that when salt water flows into the borehole the resistivity will materially change and the comparing circuit will supply an output signal.
  • the signal from the comparing circuit 71 will reposition the binary switch 65 to the opposite position from that shown so that it will transmit the pulses from the one one-half pulse per minute generator 66.
  • the binary switch 65 is coupled to a trigger circuit 73 which in turn is coupled to the switch 74.
  • the switch 74 serves to switch the AC voltage to the valve solenoid Any scattered or reflected acoustieenergy received by the transducers will be materially different, and the difference signal can be used to indicate the present of an inflow into the well.
  • three pulse generators are provided having frequencies of 6, 3 and one one-half pulses per minute.
  • the binary switches 62 and 65 are designed so that they will transmit a six pulse perminute signal when there is no inflow of fluid into the well and both the transducers 31 and 32 receive approximately the same amount of scattered and refiectedacoustic energy.
  • the difference in the two received acoustic signals will be used to switch the binary switch 62 so that three pulses per minute are transmitted.
  • the pulses transmitted by the binaryswitches are used to activate the valve mechanism 25 to produce a series of pressure pulses in the mud stream being circulated through the drill string and back to the surface.
  • Well known equipment is available for detecting the pressure pulses at the surface as well as for producing pressure pulses in a mud stream in the downhole instrument.
  • the valve 25 is merely oneexample that may be used.
  • the trigger circuit 73 may be a conventional multivibrator circuit which supplies a single output pulse for each input pulse received to operate the switch 74.
  • the switch 74 in turn, can be a solid state switching device, such as a silicon controlled rectifier for switching the high power AC voltage to the valve solenoid 24.
  • the above-described tool is operated by firstinstall ing the instrument sub in the drill string and the drill bit at the end of the instrument sub.
  • the assembly is then lowered into the well and a conventional rotary drilling practice used.
  • the two acoustic transducers 31 and 32 will be energized'to produce acoustic waves in the drilling mud.
  • the reference transducer 31 will produce acoustic waves in the drilling mud before it is circulated through the drill bit; while the transducer 32 will produce acoustic waves in the drilling mud after it is circulated through the drill bit and is returning to the surface.
  • there is any inflow of fluid, and particularly gas, into the wellbore it will be present in the drilling mud viewed by transducer 32 while it will not be present in the drilling mud viewed'by the reference transducer 31.
  • the conductivity of the drilling mud will be known and the set point of the comparingcircuit 71 set accordingly.
  • the resistivity will materially change. This change will be sensed by the comparing circuit 71 and the resulting signal used to position the binary switch65.
  • the binary switch 65 When the binary switch 65 is repositioned, it will transmit one one-half pulses to the circuit used for actuating the valve 25. This, in turn, will produce a frequency of one one-half pressure pulses per minute in the mud stream which can be detected at the surface.
  • a method for detecting an inflow of fluid into a well during the drilling of the well by rotary means using a circulating drilling fluid comprising:
  • pulses of acoustical energy are produced at two distinct locations, one location positioned to direct the acoustic energy into the drilling fluid before it has circulated through the drill bit and the other location positioned to direct the acoustic energy into the drilling fluid after it has been passed through the drill bit.
  • An apparatus for detecting the inflow of fluid into a well during the drilling of the well using rotary means including circulating a drilling fluid down the interior of the drill stem through the drill bit and back to the surface through the annulus, said apparatus comprismg;
  • transducer means said transducer means being located at the lower end of the drill stem adjacent the drill bit and disposed to produce acoustic impulses that travel through the drilling fluid in both the interior of the drill stem and the annulus, said transducer means also receiving acoustic waves that are reflected and scattered by the fluid in both the drill stem and the annulus;
  • first circuit means coupled to said transducer means to energize the transducer means to produce said acoustic impulses and to amplify the reflected and scattered acoustic waves;
  • signal transmitting means for transmitting the difference signal to the surface of said well.
  • An apparatus for detecting a fluid inflow into a well during the drilling of said well comprising:
  • transducer means disposed near the bottom of said well, said transducer means being disposed to transmit acoustic pulses through the fluid filling the well and receive the reflected and scattered acoustic waves, said transducer means generating a receiver signal related to the received acoustic waves;
  • reference signal means for generating a reference signal
  • comparison means for comparing the reference signal with the receiver signal and producing a signal related to the difference between the two signals
  • 5 and transmission means disposed in said well and coupled to the com-parison means for transmitting the signal related to the difference between the two signals to the surface.
  • said transmission means comprises a system for producing pressure pulses in the drilling fluid being circulated through the well to transmit said signal related to the difference between said two signals to the surface.
  • said signal related to the difference between the two signals comprises a first preset number of pressure pulses for indicating no inflow of fluid into the well and a second preset number of pulses for indicating an inflow of fluid that exceeds a minimum amount.
  • a method for detecting the inflow of fluid into a well filled with a drilling fluid comprising:

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US00268369A 1972-07-03 1972-07-03 Method and apparatus for detecting an inflow of fluid into a well Expired - Lifetime US3776032A (en)

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Cited By (31)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4286461A (en) * 1979-05-23 1981-09-01 Societe Nationale Elf Aquitaine (Production) Method and device for in situ detection of a mineral deposit fluid within a borehole
FR2562151A1 (fr) * 1984-03-30 1985-10-04 Nl Industries Inc Procede et appareil de determination de la pression dans des formations traversees par un sondage
US4571693A (en) * 1983-03-09 1986-02-18 Nl Industries, Inc. Acoustic device for measuring fluid properties
US4980642A (en) * 1990-04-20 1990-12-25 Baroid Technology, Inc. Detection of influx of fluids invading a borehole
US5031467A (en) * 1989-12-11 1991-07-16 Shell Oil Company Pulse echo technique for detecting fluid flow
US5130950A (en) * 1990-05-16 1992-07-14 Schlumberger Technology Corporation Ultrasonic measurement apparatus
US5214251A (en) * 1990-05-16 1993-05-25 Schlumberger Technology Corporation Ultrasonic measurement apparatus and method
US5351532A (en) * 1992-10-08 1994-10-04 Paradigm Technologies Methods and apparatus for making chemical concentration measurements in a sub-surface exploration probe
US5469736A (en) * 1993-09-30 1995-11-28 Halliburton Company Apparatus and method for measuring a borehole
US5551287A (en) * 1995-02-02 1996-09-03 Mobil Oil Corporation Method of monitoring fluids entering a wellbore
WO1997046792A1 (en) 1996-05-24 1997-12-11 Mobil Oil Corporation Pad production log tool
US6023445A (en) * 1998-11-13 2000-02-08 Marathon Oil Company Determining contact levels of fluids in an oil reservoir using a reservoir contact monitoring tool
WO2000039433A1 (fr) * 1998-12-23 2000-07-06 Elf Exploraton Production Procede de detection d'une venue de fluide de formation dans un puits en cours de forage et dispositif pour la mise en oeuvre de ce procede
US20060065392A1 (en) * 2004-09-24 2006-03-30 Geo Estratos, S.A. De C.V. System and method for crude oil production stemming from natural emanations and leaks from capped oil wells
US20060091876A1 (en) * 2004-11-04 2006-05-04 Geo Estratos, S.A. De C.V. Leak detection method and system in nonmetallic underground pipes
EP1514008A4 (en) * 2002-05-15 2006-06-21 Halliburton Energy Serv Inc BOHRLOCHFLUIDSTRÖMUNGSMESSUNG MEANS OF THE ACOUSTIC DOPPLER PRINCIPLE
US20060266198A1 (en) * 2005-05-26 2006-11-30 Jeffries Walter B Snare drum accessory
US20070005250A1 (en) * 2005-06-27 2007-01-04 Geo Estratos, S.A. De C.V. System and method for locating leaks in petroleum wells
US20080047337A1 (en) * 2006-08-23 2008-02-28 Baker Hughes Incorporated Early Kick Detection in an Oil and Gas Well
RU2325515C1 (ru) * 2007-05-23 2008-05-27 Открытое акционерное общество "Татнефть" им. В.Д. Шашина Способ эксплуатации добывающей скважины и нефтепромыслового трубопровода
US20090044617A1 (en) * 2007-08-13 2009-02-19 Baker Hughes Incorporated Downhole gas detection in drilling muds
US7506688B2 (en) 2005-09-07 2009-03-24 Geo Estratos, S.A.De Cl.V. System and method for breach detection in petroleum wells
US20090173150A1 (en) * 2005-08-01 2009-07-09 Baker Hughes Incorporated Early Kick Detection in an Oil and Gas Well
US20110000713A1 (en) * 2009-07-02 2011-01-06 Schlumberger Technology Corporation System and method for drilling using drilling fluids
US20140214328A1 (en) * 2013-01-28 2014-07-31 Westerngeco L.L.C. Salt body extraction
US9109433B2 (en) 2005-08-01 2015-08-18 Baker Hughes Incorporated Early kick detection in an oil and gas well
US9366133B2 (en) 2012-02-21 2016-06-14 Baker Hughes Incorporated Acoustic standoff and mud velocity using a stepped transmitter
US20160376886A1 (en) * 2011-08-26 2016-12-29 Schlumberger Technology Corporation Methods for evaluating inflow and outflow in a subterraean wellbore
US20170002646A1 (en) * 2015-07-01 2017-01-05 Saudi Arabian Oil Company Detecting Gas in a Wellbore Fluid
US10481297B2 (en) 2013-01-28 2019-11-19 Westerngeco L.L.C. Fluid migration pathway determination
US11263801B2 (en) 2017-03-31 2022-03-01 Schlumberger Technology Corporation Smooth surface wrapping of features in an imaged volume

Families Citing this family (1)

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Publication number Priority date Publication date Assignee Title
FR2530286B1 (fr) * 1982-07-13 1985-09-27 Elf Aquitaine Procede et systeme de detection d'un fluide de gisement dans un puits de forage

Citations (2)

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US3305825A (en) * 1963-08-26 1967-02-21 Mobil Oil Corp Telemetering device and system for pumping wells
US3693428A (en) * 1970-07-24 1972-09-26 Jean Pierre Le Peuvedic Hydraulic control device for transmitting measuring values from the bottom of a well to the surface as pressure pulses through the drilling mud

Patent Citations (2)

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US3305825A (en) * 1963-08-26 1967-02-21 Mobil Oil Corp Telemetering device and system for pumping wells
US3693428A (en) * 1970-07-24 1972-09-26 Jean Pierre Le Peuvedic Hydraulic control device for transmitting measuring values from the bottom of a well to the surface as pressure pulses through the drilling mud

Cited By (43)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4286461A (en) * 1979-05-23 1981-09-01 Societe Nationale Elf Aquitaine (Production) Method and device for in situ detection of a mineral deposit fluid within a borehole
US4571693A (en) * 1983-03-09 1986-02-18 Nl Industries, Inc. Acoustic device for measuring fluid properties
FR2562151A1 (fr) * 1984-03-30 1985-10-04 Nl Industries Inc Procede et appareil de determination de la pression dans des formations traversees par un sondage
US5031467A (en) * 1989-12-11 1991-07-16 Shell Oil Company Pulse echo technique for detecting fluid flow
US4980642A (en) * 1990-04-20 1990-12-25 Baroid Technology, Inc. Detection of influx of fluids invading a borehole
USRE34975E (en) * 1990-05-16 1995-06-20 Schlumberger Technology Corporation Ultrasonic measurement apparatus
US5214251A (en) * 1990-05-16 1993-05-25 Schlumberger Technology Corporation Ultrasonic measurement apparatus and method
US5317111A (en) * 1990-05-16 1994-05-31 Schlumberger Technology Corporation Ultrasonic measurement apparatus
US5354956A (en) * 1990-05-16 1994-10-11 Schlumberger Technology Corporation Ultrasonic measurement apparatus
US5130950A (en) * 1990-05-16 1992-07-14 Schlumberger Technology Corporation Ultrasonic measurement apparatus
US5351532A (en) * 1992-10-08 1994-10-04 Paradigm Technologies Methods and apparatus for making chemical concentration measurements in a sub-surface exploration probe
US5469736A (en) * 1993-09-30 1995-11-28 Halliburton Company Apparatus and method for measuring a borehole
US5551287A (en) * 1995-02-02 1996-09-03 Mobil Oil Corporation Method of monitoring fluids entering a wellbore
WO1997046792A1 (en) 1996-05-24 1997-12-11 Mobil Oil Corporation Pad production log tool
US6023445A (en) * 1998-11-13 2000-02-08 Marathon Oil Company Determining contact levels of fluids in an oil reservoir using a reservoir contact monitoring tool
WO2000039433A1 (fr) * 1998-12-23 2000-07-06 Elf Exploraton Production Procede de detection d'une venue de fluide de formation dans un puits en cours de forage et dispositif pour la mise en oeuvre de ce procede
EP1514008A4 (en) * 2002-05-15 2006-06-21 Halliburton Energy Serv Inc BOHRLOCHFLUIDSTRÖMUNGSMESSUNG MEANS OF THE ACOUSTIC DOPPLER PRINCIPLE
US20060065392A1 (en) * 2004-09-24 2006-03-30 Geo Estratos, S.A. De C.V. System and method for crude oil production stemming from natural emanations and leaks from capped oil wells
US20060091876A1 (en) * 2004-11-04 2006-05-04 Geo Estratos, S.A. De C.V. Leak detection method and system in nonmetallic underground pipes
US7095222B2 (en) 2004-11-04 2006-08-22 Geo Estratos, S.A. De C.V. Leak detection method and system in nonmetallic underground pipes
US20060266198A1 (en) * 2005-05-26 2006-11-30 Jeffries Walter B Snare drum accessory
US20070005250A1 (en) * 2005-06-27 2007-01-04 Geo Estratos, S.A. De C.V. System and method for locating leaks in petroleum wells
US9109433B2 (en) 2005-08-01 2015-08-18 Baker Hughes Incorporated Early kick detection in an oil and gas well
US8794062B2 (en) 2005-08-01 2014-08-05 Baker Hughes Incorporated Early kick detection in an oil and gas well
US20090173150A1 (en) * 2005-08-01 2009-07-09 Baker Hughes Incorporated Early Kick Detection in an Oil and Gas Well
US7506688B2 (en) 2005-09-07 2009-03-24 Geo Estratos, S.A.De Cl.V. System and method for breach detection in petroleum wells
WO2008024807A3 (en) * 2006-08-23 2013-10-17 Baker Hughes Incorporated Early kick detection in an oil and gas well
GB2454424B (en) * 2006-08-23 2011-11-23 Baker Hughes Inc Early kick detection in an oil and gas well
US20080047337A1 (en) * 2006-08-23 2008-02-28 Baker Hughes Incorporated Early Kick Detection in an Oil and Gas Well
WO2008024806A3 (en) * 2006-08-23 2008-04-24 Baker Hughes Inc Early kick detection in an oil and gas well
RU2325515C1 (ru) * 2007-05-23 2008-05-27 Открытое акционерное общество "Татнефть" им. В.Д. Шашина Способ эксплуатации добывающей скважины и нефтепромыслового трубопровода
US20090044617A1 (en) * 2007-08-13 2009-02-19 Baker Hughes Incorporated Downhole gas detection in drilling muds
US7814782B2 (en) * 2007-08-13 2010-10-19 Baker Hughes Incorporated Downhole gas detection in drilling muds
US20110000713A1 (en) * 2009-07-02 2011-01-06 Schlumberger Technology Corporation System and method for drilling using drilling fluids
US9010460B2 (en) * 2009-07-02 2015-04-21 Schlumberger Technology Corporation System and method for drilling using drilling fluids
US20160376886A1 (en) * 2011-08-26 2016-12-29 Schlumberger Technology Corporation Methods for evaluating inflow and outflow in a subterraean wellbore
US10190407B2 (en) * 2011-08-26 2019-01-29 Schlumberger Technology Corporation Methods for evaluating inflow and outflow in a subterraean wellbore
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