EP1731709B1 - Procédé et système permettant d'effectuer des opérations et d'améliorer la production dans des puits - Google Patents

Procédé et système permettant d'effectuer des opérations et d'améliorer la production dans des puits Download PDF

Info

Publication number
EP1731709B1
EP1731709B1 EP06076630A EP06076630A EP1731709B1 EP 1731709 B1 EP1731709 B1 EP 1731709B1 EP 06076630 A EP06076630 A EP 06076630A EP 06076630 A EP06076630 A EP 06076630A EP 1731709 B1 EP1731709 B1 EP 1731709B1
Authority
EP
European Patent Office
Prior art keywords
well
casing
tool
reader device
radio frequency
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.)
Expired - Lifetime
Application number
EP06076630A
Other languages
German (de)
English (en)
Other versions
EP1731709A2 (fr
EP1731709A3 (fr
Inventor
Philip M. Snider
Joseph A. Zierolf
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.)
Marathon Oil Co
Original Assignee
Marathon Oil Co
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
Priority claimed from US09/586,648 external-priority patent/US7283061B1/en
Application filed by Marathon Oil Co filed Critical Marathon Oil Co
Publication of EP1731709A2 publication Critical patent/EP1731709A2/fr
Publication of EP1731709A3 publication Critical patent/EP1731709A3/fr
Application granted granted Critical
Publication of EP1731709B1 publication Critical patent/EP1731709B1/fr
Anticipated expiration legal-status Critical
Expired - Lifetime legal-status Critical Current

Links

Images

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/006—Accessories for drilling pipes, e.g. cleaners
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/11—Perforators; Permeators
    • E21B43/119—Details, e.g. for locating perforating place or direction
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/04—Measuring depth or liquid level

Definitions

  • This invention relates to generally to wells used in the production of fluids such as oil and gas. More specifically, this invention relates to a method and system for performing various operations and for improving production in wells.
  • drill stem components having coded electronic identification tags recessed in the external surface thereof can be automatic tallied as they enter or are withdrawn from well bore by means of a stationary reader at the drill floor.
  • different downhole operations are typically performed at some depth within the well, but are controlled at the surface.
  • a perforating process is one type of downhole operation that is used to perforate a well casing.
  • a conventional perforating process is performed by placing a perforating tool (i.e., perforating gun) in a well casing, along a section of the casing proximate to a geological formation of interest.
  • the perforating tool carries shaped charges that are detonated using a signal transmitted from the surface to the charges. Detonation of the charges creates openings in the casing and concrete around the casing, which are then used to establish fluid communication between the geological formation, and the inside diameter of the casing.
  • a downhole operation is the setting of packers within the well casing to isolate a particular section of the well or a particular geological formation.
  • a packer can be placed within the well casing at a desired depth, and then set by a setting tool actuated from the surface.
  • Other exemplary downhole operations include the placement of logging tools at a particular geological formation or depth within the well casing, and the placement of bridge plugs, casing patches, tubulars, and associated tools in the well casing.
  • a downhole operation involves ascertaining the depth in the well where the operation is to be performed.
  • the depth is typically ascertained using well logs.
  • a conventional well log includes continuous readings from a logging instrument, and an axis which represents the well depths at which the readings were obtained.
  • the instrument readings measure rock characteristics such as natural gamma ray radiation, electrical resistivity, density and acoustic properties. Using these rock characteristics geological formations of interest within the well, such as oil and gas bearing formations, can be identified.
  • the well is initially logged "open hole” which becomes the bench mark for all future logs. After the well is cased, a cased hole log is then prepared and correlated, or "tied in", to the open hole log.
  • a tool can be placed at a desired depth within the well, and then actuated as required to perform the downhole operation.
  • a positioning mechanism such as a wire line or coiled tubing, coupled to an odometer.
  • Figure 1 illustrates a prior art perforating process being performed in an oil and gas well 10.
  • the well 10 includes a well bore 12, and a casing 14 within the well bore 12 surrounded by concrete 16.
  • the well 10 extends from an earthen surface 18 through geological formations within the earth, which are represented as Zones A, B and C.
  • the casing 14 is formed by tubular elements, such as pipe or tubing sections, connected to one another by collars 20.
  • the tubular elements that form the casing 14 are about 40 feet long so that the casing collars 20 are forty feet apart.
  • tubular elements with shorter lengths e.g., twenty feet
  • two of the casing collars 20 are only twenty feet apart.
  • a perforating tool 22 has been lowered into the casing 14 on a wire line 24.
  • a mast 26 and pulleys 28 support the wire line 24, and a wire line unit 30 controls the wire line 24.
  • the wire line unit 30 includes a drive mechanism 32 that lowers the wire line 24 and the tool 22 into the well 10, and raises the wire line 24 and the tool 22 out of the well 10 at the completion of the process.
  • the wire line unit 30 also includes an odometer 34 that measures the unwound length of the wire line 24 as it is lowered into the well 10, and equates this measurement to the depth of the tool 22 within the well.
  • the open hole log 36 includes various instrument readings, such as gamma ray readings 38 and spontaneous potential (SP) readings 40 which are plotted as a function of depth in feet. For simplicity only a portion of the open hole log 36, from about 7000 feet to about 7220 feet, is illustrated. However, in actual practice the entire well 10 from the surface 18 to the bottom of the well 10 may be logged.
  • the open hole log 36 permits skilled artisans to ascertain the oil and gas containing formations within the well 10 and the most productive intervals of those formations. For example, based on the gamma ray readings 38 and the SP readings 40 it is determined that Zone A may contain oil and gas reserves. It is thus desired to perforate the casing 14 along a section thereof proximate to Zone A.
  • casing collar log 42 In addition to the open hole log 36, following casing of the well 10, cased hole gamma ray readings 44 are made, and a casing collar log 42 can be prepared.
  • the casing collar log 42 is also referred to as a PDC log (perforating depth control log).
  • the casing collar log 42 can be used to identify the section of the casing 14 proximate to Zone A where the perforations are to be made.
  • the casing collar log 42 can be accurately correlated, or "tied in", to the open hole log 36.
  • conventional positioning mechanisms such as the wire line unit 30, it may be difficult to accurately place the perforating tool 22 at the required depth within the well. For example, factors such as stretching, elongation from thermal effects, sinusoidal and helical buckling, and deformation of the wire line 24 can affect the odometer readings, and the accuracy of the odometer readings relative to the open hole odometer readings.
  • the odometer readings which indicate the depth of the perforating tool 22 may not equate to the actual depths, as reflected in the open hole log 36 and the casing collar log 42.
  • the odometer readings differ from the depths identified in the open hole log 36 and the casing collar log 42 by about 40 feet.
  • correlative joint logging and wire logging techniques have been developed in the art.
  • one prior art technique uses electronic joint sensors, and electrically conductive wire line, to determine joint-to-joint lengths, and to correlate the odometer readings of the wire line to the casing collar log.
  • these correlative joint logging and wire line logging techniques are accurate, they are expensive and time consuming. In particular, additional crews and surface equipment are required, and additional wire line footage charges are incurred.
  • computational errors also introduce inaccuracies in depth computations.
  • a tool operator can make computational errors by thinking one number (e.g., 7100), while the true number may be different (e.g., 7010).
  • the tool operator may position the tool by compensating a desired amount in the uphole direction, when in reality the downhole direction should have been used.
  • the present invention is directed to an improved method and system for performing operations and processes in wells, in which the depths of down hole tools are accurately ascertained and used to control the operations and processes.
  • the well includes a well bore, and a well casing, extending from an earthen or subsea surface into various geological zones within the earth.
  • the well casing includes lengths of pipe or tubing joined together by casing collars.
  • the method described herein includes the initial step of providing identification devices at spaced intervals along the length of the well casing.
  • the identification devices can comprise active or passive radio identification devices installed in each casing collar of the well casing.
  • Each radio identification device is uniquely identified, and its depth, or location, within the well is accurately ascertained by correlation to well logs.
  • each casing collar is uniquely identified by the radio identification device contained therein, and a record of the well including the depth of each casing collar and identification device is established.
  • the method we describe also includes the step of providing a reader device, and a transport mechanism for moving the reader device through the well casing proximate to the identification devices.
  • the reader device comprises a radio frequency transmitter and receiver configured to provide transmission signals for reception by the identification devices.
  • the identification devices are configured to receive the transmission signals, and to transmit response signals back to the reader device.
  • the transport mechanism for the reader device can comprise a wire line, tubulars, coil tubing, a robotic mechanism, a fluid transport mechanism such as a pump or a blower, a free fall arrangement, or a controlled fall arrangement such as a parachute.
  • the reader device is also configured to transmit control signals for controlling a process tool, as a function of the response signals from the identification devices.
  • the reader device can control a perforating tool configured to perforate the well casing.
  • the reader device and the perforating tool can be transported together through the well casing past the identification devices.
  • the reader device can be programmed to transmit the control signal to detonate the perforating tool, upon reception of a response signal from an identification device located at a predetermined depth of location within the well. Stated differently, the reader device can be programmed to control the perforating tool responsive to locating a specific identification device.
  • the reader device can be configured to control setting tools for packers, bridge plugs or casing patches, to control instrument readings from logging tools, and to control jet cutters and similar tools.
  • the true depth of the process tool can be ascertained in real time by the reader device using response signals from the identification devices. Accordingly, there is no need to ascertain the depth of the tool using an odometer, and expensive wire logging techniques. In addition, operator computational errors are reduced because true depth readings can be provided without the requirement of additional computations. Further, for some processes, there is no need to transmit signals to the surface, as the reader device can be programmed to control the process In situ within the well.
  • the method described herein can also be practiced by transmission of the control signals from the reader device to a controller or computer at the surface, and control of the process tool by the controller or computer.
  • control of the process tool can be performed dynamically as the process tool moves through the well with the reader device, or statically by stopping the process tool at a required depth.
  • the method described herein can be used to control a multi stage process, or to control a tool configured to perform multiple processes.
  • a combination packer setting and perforating tool can be configured to perform packer setting and perforating processes, as a function of true depth readings obtained using the method of the invention.
  • the system includes the identification devices installed in casing collars at spaced intervals along the well casing.
  • the identification devices include a programmable element, such as a transceiver chip for receiving and storing identification information, such as casing collar and depth designations.
  • Each identification device can be configured as a passive device, an active device having an antenna, or a passive device which can be placed in an active state by transmission of signals through well fluids.
  • the system also includes the reader device and the process tool configured for transport through the well casing.
  • the reader device includes one or more programmable memory devices, such as semiconductor chips configured to receive and store information.
  • the reader device also includes a power source such as a power line to the surface, or a battery.
  • the reader device includes a telemetry circuit for transmitting the control signals, which can be used to control the process tool, and to provide depth and other information to operators and equipment at the surface.
  • the system can also include a computer configured to receive and process the control signals, and to provide and store information in visual or other form for well operators and equipment.
  • the system can include a controller configured to process the control signals for controlling the process tool and various process equipment. The controller can be located at the surface, or on the process tool, to provide a self contained system. Also, the system can be transported to a well site in the form of a kit, and then assembled at the well site.
  • a system 50 constructed in accordance with the invention is illustrated.
  • the system 50 is installed in a subterranean well 52, such as an oil and gas production well.
  • the system 50 is configured to perform a perforating process in the well 52.
  • the perforating process performed in accordance with the invention provides an improved well 52, and improves production from the well 52.
  • the well 52 includes a well bore 54, and a well casing 56 within the well bore 54 surrounded by concrete 56.
  • the well 52 extends from an earthen surface 60 through geological formations within the earth, which are represented as Zones E, F and G.
  • the earthen surface 60 can be the ground, or alternately a structure, such as an oil platform located above water.
  • the well 52 extends generally vertically from the surface 60 through Zones E, F, and G.
  • the method can also be practiced on inclined wells, and on horizontal wells.
  • the well casing 56 comprises a plurality of tubular elements 62, such as lengths of metal pipe or tubing, connected to one another by collars 64.
  • the casing 56 includes an inside diameter adapted to transmit fluids into, or out of, the well 52, and an outside diameter surrounded by the concrete 58.
  • the collars 64 can comprise couplings having female threads adapted for mating engagement with male threads on the tubular elements 62. Alternately, the collars 64 can comprise weldable couplings adapted for welding to the tubular elements 62.
  • the casing 56 is illustrated as having the same outside diameter and inside diameter throughout its length. However, it is to be understood that the casing 56 can vary in size at different depths in the well 52, as would occur by assembling tubulars with different diameters.
  • the casing 56 can comprise a telescoping structure in which the size thereof decreases with increasing depth.
  • Zone F of the well 52 may contain oil and gas. It is thus desired to perforate the casing 56 proximate to Zone F to establish fluid communication between Zone F, and the inside diameter of the well casing 56.
  • the system 50 For performing the perforating process, the system 50 includes a perforating tool 68, and a reader device 70 in signal communication with the perforating tool 68.
  • the system 50 also includes a plurality of identification devices 72 ( Figure 3D ) attached to the collars 64 on the casing 56, and readable by the reader device 70.
  • the system 50 includes a transport mechanism 66W for transporting the perforating tool 68 and the reader device 70 through the well casing 56 to Zone F. If desired, the system 50 can be transported to the well 52 as a kit, and then assembled at the well 52.
  • the perforating tool 68 includes a detonator 74 (illustrated schematically) and a detonator cord 76 in signal communication with the detonator 74.
  • the detonator 74 can comprise a commercially available impact or electrical detonator configured for actuation by a signal from the reader device 70.
  • the detonator cord 76 can comprise a commercially available component.
  • the detonator 74 and the detonator cord 76 are configured to generate and apply a threshold detonating energy to initiate a detonation sequence of the perforating tool 68.
  • the detonator 74 is located on, or within, the perforating tool 68.
  • the perforating tool 68 also includes one or more charge carriers 78 each of which comprises a plurality of charge assemblies 80.
  • the charge carriers 78 and charge assemblies 80 can be similar to, or constructed from, commercially available perforating guns. Upon detonation, each charge assembly 80 is adapted to blast an opening 82 through the casing 56 and the concrete 58, and into the rock or other material that forms Zone F.
  • each collar 64 includes an identification device 72.
  • Each identification device 72 can be attached to a resilient o-ring 86 placed in a groove 84 within each collar 64.
  • the identification devices 72 comprise passive radio identification devices (PRIDs).
  • PRIDs are commercially available and are widely used in applications such as to identify merchandise in retail stores, and books in libraries.
  • the PRIDs include a circuit which is configured to resonate upon reception of radio frequency energy from a radio transmission of appropriate frequency and strength. Passive PRIDs do not require a power source, as the energy received from the transmission signal provides the power for the PRIDs to transmit a reply signal during reception of the transmission signal.
  • the identification device 72 includes an integrated circuit chip, such as a transceiver chip, having memory storage capabilities.
  • the integrated circuit chip can be configured to ' receive RF signals and to encode and store data based on the signals.
  • each identification device 72 can be uniquely identified such that each collar 64 is also uniquely identified. This identification information is indicated by the C1-C8 designations in Figures 3A and 3B .
  • the depth of each collar 64 can be ascertained using well logs, as previously explained and shown in Figure 1 . The depth information can then be correlated to the identification information encoded into the identification device 72. A record can thus be established identifying each collar 64 and its true depth in the well 52.
  • identification device 72A can be in the form of an active device having a separate power source such as a battery.
  • the identification device 72A can include an antenna 89 for transmitting signals.
  • an identification device (not shown) can be configured to transmit signals through a well fluid or other transmission medium within the well 52. Such an identification device is further described in previously cited parent application serial No. 09/286,650 now US Patent No. 6,333.699 .
  • the identification device 72A can be contained in a threaded mounting device 87.
  • the threaded mounting device 87 can comprise a rigid, non-conductive material such as a plastic.
  • the threaded mounting device 87 is configured to be screwed into the middle portions of the casing collar 64 ( Figure 3D ), and to be retained between adjacent tubular elements of the casing 56.
  • the threaded mounting device 87 includes a circumferential groove 91 for the antenna 89, and a recess 93 for the identification device 72A. If desired, the antenna 89 and the identification device 72A can be retained in the groove 91 and the recess 93 using an adhesive or a suitable fastener.
  • the reader device 70 is shown in greater detail.
  • the reader device 70 is configured to transmit RF transmission signals at a selected frequency to the identification devices 72, and to receive RF response signals from the identification devices 72.
  • the reader device 70 includes a base member 77 having a transmitter 73 configured to transmit transmission signals of a first frequency to the identification devices 72.
  • the reader device 70 includes a receiver 71 on the base member 77 configured to receive signals of a second frequency from the identification devices 72.
  • the transmitter 73 is configured to provide relatively weak transmission signals such that only an identification device 72 within a close proximity (e.g., one foot) of the reader device 70 receives the transmission signals.
  • the antenna of the reader device 70 can be configured to provide highly directional transmission signals such that the transmission signals radiate essentially horizontally from the reader device 70. Accordingly, the transmission signals from the reader device 70 are only received by a single identification device 72 as the reader devices passes in close proximity to the single identification device 72.
  • the reader device 70 includes a cover 79 made of an electrically non-conductive material, such as plastic or fiberglass.
  • the reader device 70 also includes o-rings 75 on the base member 77 for sealing the cover 79, and a cap member 81 attached to the base member 77 which secures the cover 79 on the base member 77.
  • the reader device 70 includes spacer elements 83 formed of an electrically non-conductive material such as ferrite, ceramic or plastic, which separate the transmitter 73 and the receiver 71 from the base member 77.
  • the base member 77 is generally cylindrical in shape, and the spacer elements 83 comprise donuts with a half moon or contoured cross section.
  • each identification device 72 includes a memory device 110, in the form of a programmable integrated circuit chip, such as a transceiver chip, configured to receive and store identification information.
  • the identification information can uniquely identify each casing collar 64 with an alpha numerical, numerical or other designator.
  • the depth of each uniquely identified casing collar 64 can be ascertained.
  • the reader device 70 includes the transmitter 73 for transmitting transmission signals to the identification devices 72, and the receiver 71 for receiving the response signals from the identification devices 72.
  • the reader device 70 can be powered by a suitable power source, such as a battery, or a power supply at the surface.
  • the reader device 70 includes a memory device 112, such as one or more integrated circuit chips, configured to receive and store programming information.
  • the reader device 70 also includes a telemetry circuit 114 configured to transmit control signals in digital or other form, through software 116 to a controller 118, or alternately to a computer 122.
  • the software 116 can be included in the controller 118, or in the computer 122.
  • the computer 122 can comprise a portable device such as a lap top which can be pre-programmed and transported to the well site.
  • the computer 122 can include a visual display for displaying information received from the reader device 70.
  • the controller 118, or the computer 122 interface with tool control circuitry 120, which is configured to control the perforating tool 68 as required.
  • the tool control circuitry 120 is in signal communication with the detonator 74 ( Figure 3C ) of the perforating tool 68.
  • the tool control circuitry 120 can be located on the perforating tool 68, on the reader device 70, or at the surface.
  • the reader device 70 is programmed to transmit control signals to the tool control circuitry 120, as a function of response signals received from the identification devices 72.
  • coupling C4 is located proximate to the upper level, or entry point into Zone F.
  • the reader device 70 can be programmed to transmit actuation control signals through the tool control circuitry 120 to the detonator 74 ( Figure 3C ), when it passes coupling C4 and receives response signals from the identification device 72 contained in coupling C4. Because coupling C4 is uniquely identified by the identification device 72 contained therein, and the depth of coupling C4 has been previously identified using well logs, the perforating process can be initiated in real time, as the perforating tool 68 passes coupling C4 and enters the section of the well casing 56 proximate to Zone F.
  • the perforating tool 68 and reader device 70 can be transported through the well casing 56 with a certain velocity (V).
  • the reader device 70 requires a certain time period (T1) to transmit transmission signals to the identification device 72 in coupling C4, and to receive response signals from the identification device 72 in coupling C4.
  • a certain time period (T2) is required for transmitting signals to the tool control circuitry 120 and to the detonator 74 ( Figure 3C ).
  • the charge assemblies 80 require a certain time period (T3) before detonation, explosion and perforation of the casing 56 occur. All of these factors can be considered in determining which identification device 72 in which casing 64 will be used to make the reader device 70 transmit actuation control signals through the tool control circuitry 120 to the detonator 74 ( Figure 3C ).
  • the velocity (V) of the perforating tool 68 and the reader device 70 can be selected as required.
  • a spacer element 88 can be used to space the perforating tool 68 from the reader device 70 by a predetermined distance (D).
  • the perforating tool 68 can be above the reader device 70 (i.e., closer to the surface 60), or alternately as shown in Figure 5B can be below the reader device 70 (i.e., farther from the surface 60).
  • the perforating tool 68 can be stopped when the required depth is reached, and a static detonation sequence performed.
  • the reader device 70 can be programmed to send a signal for stopping the perforating tool 68 when it reaches coupling C6.
  • the signal from the reader device 70 can be used to control the wire line unit 92 and stop the wire line 90.
  • the detonation and explosive sequence can then be initiated by signals from the tool control circuit 120, with the perforating tool 68 in a static condition at the required depth.
  • signals from the reader device 70 can be used to generate a visual display 124, such as a computer screen on the computer 122, which is viewable by an operator at the surface.
  • the visual display 124 is titled “True Depth Systems” and includes a power switch for enabling power to the reader device 70 and other system components.
  • the visual display 124 also includes a "Depth Meter” that indicates the depth of the reader device 70 (or the perforating tool 68) within the well 52.
  • the visual display 124 also includes "Alarm Indicators” including a "Well Alarm Top” indicator, a "Well Alarm Bottom” indicator, and an “Explosive Device” indicator.
  • the "Alarm Indicators” are similar to stop lights with green, yellow and red lights to indicate varying conditions.
  • the visual display 124 also includes "Power Indicators” including a "True Depth Reader” power indicator, a "True Depth Encoder” power indicator, and a “System Monitor” power indicator.
  • the visual display 124 includes various "Digital Indicators”. For example, a "Line Speed” digital indicator indicates the speed at which the reader device 70, and the perforating tool 68, are being transported through the well casing 56.
  • An “Encoder Depth” digital indicator indicates the depth of each identification device 72 as the reader device 70 passes by the identification devices 72.
  • a "True Depth” indicator indicates the actual depth of the reader device 70 in real time as it is transported through the well casing 56.
  • the visual display 124 also includes a "TDS ID” indicator that indicates an ID number for each identification device 72.
  • the visual display 124 includes a "TDS Description” indicator that further describes each identification device 72 (e.g., location in a specific component or zone).
  • the visual display 124 also includes a "Time” indicator that can be used as a time drive (forward or backward) for demonstration or review purposes.
  • the visual display 124 includes an "API Log” which indicates log information, such as gamma ray or SPE readings, from the previously described well logs, correlated to the "Digital Indicators" for depth.
  • the transport mechanism 66W includes a wire line 90 operable by a wire line unit 92, substantially as previously explained and shown in Figure 1 .
  • the wire line 90 can comprise a slick line, an electric line, a braided line, or coil tubing. If the controller 118, or the computer 122, is located at the surface 60, the wire line 90 can be used to establish signal communication between the reader device 70 and the controller 118 or the computer 122.
  • a transport mechanism 66P comprises a pump for pumping a conveyance fluid through the inside diameter of the casing 56. The pumped conveyance fluid then transports the perforating tool 68 and the reader device 70 through the casing 56.
  • a transport mechanism 66R comprises one or more robotic devices attached to the perforating tool 68 and the reader device 70, and configured to transport the perforating tool 68 and the reader device 70 through the casing 56.
  • a transport mechanism 66G comprises gravity (G) such that the perforating tool 68 and the reader device 70 free fall through the casing 56.
  • the free fall can be through a well fluid within the casing 56, or through air in the casing 56.
  • a transport mechanism 66PA includes a parachute which controls the rate of descent of the perforating tool 68 and the reader device 70 in the casing 56. Again, the parachute can operate in a well fluid, or in air contained in the casing 56.
  • FIG. 7A-7C an alternate embodiment system 50A constructed in accordance with the invention is illustrated.
  • the system 50A is installed in a subterranean well 52A, such as an oil and gas production well.
  • the system 50A is configured to perform a packer setting process in the well 52A.
  • the well 52A includes a well bore 54A, and a well casing 56A within the well bore 54A surrounded by concrete 58A.
  • the well casing 56A comprises a plurality of tubular elements 62A, such as lengths of metal pipe or tubing, connected to one another by collars 64A.
  • the well 52A extends from an earthen surface 60A through geological formations within the earth, which are represented as Zones H and I.
  • the system 50A includes a packer setting tool 68A, an inflation device 98A for the packer setting tool 68A, and a reader device 70A in signal communication with the packer setting tool 68A.
  • the inflation device 98A is located on the surface 60A such that a wire, or other signal transmission medium must be provided between the packer setting tool 68A and the inflation device 98A.
  • the packer setting tool 68A can include an inflatable packer element designed for inflation by the inflation device 98A and configured to sealingly engage the inside diameter of the casing 56A.
  • the inflatable packer element of the packer setting tool 68A has been inflated to seal the inside diameter of the casing 56A proximate to Zone I.
  • the system 50A also includes a plurality of identification devices 72 ( Figure 3D ) attached to the collars 64A on the casing 56A, and readable by the reader device 70A.
  • the system 50A includes a transport mechanism 66A for transporting the packer setting tool 68A and the reader device 70A through the well casing 56A to Zone I.
  • the transport mechanism 66A comprises a tubing string formed by tubular elements 102A.
  • each tubular element 102A includes a male tool joint 94A on one end, and a female tool joint 96A on an opposing end. This permits the tubular elements 102A to be attached to one another to form the transport mechanism 66A.
  • the packer setting tool 68A can include a central mandrel in fluid communication with the inside diameter of the transport mechanism 66A.
  • the reader device 70A is programmed to transmit a control signal to the inflation device 98A upon actuation by a selected identification device 72 ( Figure 3D ).
  • a selected identification device 72 Figure 3D
  • coupling C4A is located proximate to the upper level, or entry point into Zone I. Since it is desired to inflate the inflatable packer element of the packer setting tool 68A while it is proximate to Zone I, the reader device 70A can be programmed to transmit the control signal to the inflation device 68A when it reaches coupling C4A.
  • a spacer element 88A separates the packer setting tool 68A and the reader device 70A.
  • the packer setting tool 68A is located downhole relative to the reader device 70A.
  • the packer setting tool 68A can be stopped at a particular coupling (e.g., coupling C5A) and then inflated as required.
  • the reader device 70A can be programmed to transmit the control signals to the visual display 124 ( Figure 4B ) on the surface 60A when the packer tool 68A passes a coupling 64A at the required depth. The operator can then control the inflation device 98A to initiate inflation of the packer setting tool 68A. Alternately the inflation sequence can be initiated automatically by the tool control circuit 120 ( Figure 4A ).
  • the method described herein provides an improved well.
  • the well 52 can be perforated in the selected zone, or in a selected interval of the selected zone. Production from the well 52 is thus optimized and the well 52 Is able to produce more fluids, particularly oil and gas.
  • a combination tool 130 is provided.
  • the combination tool 134 includes a packer setting tool 132 and a perforating tool 134, which function substantially as previously described for the packer setting tool 68A ( Figure 7B ), and the perforating tool 68 ( Figure 3A ) previously described.
  • the combination tool 134 includes the reader device 70 and the casing 56 includes identification devices 72 ( Figure 3D ) substantially as previously described.
  • the combination tool 130 is transported through the casing 56 using the gravity transport mechanism 66G. Alternately, any of the other previously described transport mechanisms can be employed.
  • the packer setting tool 132 is actuated such that an inflatable packer element of the tool 132 seals the casing 56 at a desired depth.
  • the packer setting tool 132 is a self contained unit, with an integral inflation source.
  • the reader device 70 provides control signals for controlling the packer setting tool 132, and the packer setting process.
  • the inflatable packer element of the packer setting tool 132 can be inflated when the reader device 70 passes a selected coupling 64, and receives a response signal from the identification device 72 contained within the selected coupling 64.
  • the perforating tool 134 separates from the packer setting tool 132 and continues to free fall through the casing 56.
  • the perforating tool 132 is controlled such that detonation and explosive sequences are initiated substantially as previously described.
  • the reader device 70 provides control signals, for controlling the perforating tool 132 to initiate the detonation and explosive sequences at the proper depth.
  • explosion of the charge assemblies 80 ( Figure 3C ) of the perforating tool 134 forms openings in the casing 58 and the concrete 58.

Claims (19)

  1. Puits (52 ; 52A) comprenant un tuyau (56 ; 56A) installé dans un sondage (54 ; 54A), caractérisé par :
    au moins un dispositif d'identification de fréquence radio (72) installé à l'intérieur dudit tuyau, codé avec une désignation de profondeur unique et configuré pour recevoir un signal de fréquence radio (70) transmis à partir de l'intérieur dudit tuyau.
  2. Puits selon la revendication 1, dans lequel ledit tuyau est un tubage.
  3. Puits selon la revendication 2, dans lequel ledit tubage est fixé dans ledit sondage par du ciment (58 ; 58A).
  4. Puits selon la revendication 2, dans lequel ledit au moins un dispositif d'identification de fréquence radio est installé à un point intermédiaire à l'intérieur dudit tubage.
  5. Puits selon la revendication 2, dans lequel ledit tubage comporte une pluralité de sections (62 ; 62A) avec des sections contiguës définissant un joint entre celles-ci.
  6. Puits selon la revendication 5, dans lequel chacun dudit au moins un dispositif d'identification de fréquence radio est installé dans un de ladite pluralité de joints.
  7. Puits selon la revendication 5, comprenant en outre :
    un dispositif d'étanchéité (86) positionné dans ledit joint.
  8. Puits selon la revendication 5, dans lequel chacun dudit au moins un dispositif d'identification de fréquence radio est installé à un point intermédiaire le long d'une de ladite pluralité de sections.
  9. Puits selon la revendication 2, dans lequel une pluralité de dispositifs d'identification de fréquence radio sont installés à l'intérieur dudit tubage.
  10. Puits selon la revendication 9, dans lequel ledit tubage comporte une pluralité de joints.
  11. Puits selon la revendication 10, dans lequel chacun de ladite pluralité de joints comporte un de ladite pluralité de dispositifs d'identification de fréquence radio installé dans celui-ci.
  12. Puits selon la revendication 1, dans lequel ledit au moins un dispositif d'identification de fréquence radio est un dispositif actif d'identification de fréquence radio.
  13. Puits selon la revendication 1, dans lequel ledit au moins un dispositif d'identification de fréquence radio est un dispositif passif d'identification de fréquence radio.
  14. Puits selon la revendication 1, dans lequel chacun dudit au moins un dispositif d'identification de fréquence radio est configuré pour fournir une réponse distincte.
  15. Puits selon la revendication 1, dans lequel ledit au moins un dispositif d'identification de fréquence radio comporte une antenne (89).
  16. Puits selon la revendication 15, dans lequel ladite antenne est configurée en forme de boucle.
  17. Puits selon la revendication 8, dans lequel ledit au moins un dispositif d'identification de fréquence radio est fixé à l'intérieur dudit tubage au moyen d'un manchon.
  18. Puits selon la revendication 17, dans lequel ledit au moins un dispositif d'identification de fréquence radio comporte une antenne (89).
  19. Puits selon la revendication 1, dans lequel ladite désignation de profondeur est déterminée à l'aide de diagraphies de sondage.
EP06076630A 2000-06-01 2001-05-25 Procédé et système permettant d'effectuer des opérations et d'améliorer la production dans des puits Expired - Lifetime EP1731709B1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US09/586,648 US7283061B1 (en) 1998-08-28 2000-06-01 Method and system for performing operations and for improving production in wells
EP01941647A EP1287230B1 (fr) 2000-06-01 2001-05-25 Procede et systeme permettant d'effectuer des operations et d'ameliorer la production dans des puits

Related Parent Applications (2)

Application Number Title Priority Date Filing Date
EP01941647.8 Division 2001-05-25
EP01941647A Division EP1287230B1 (fr) 2000-06-01 2001-05-25 Procede et systeme permettant d'effectuer des operations et d'ameliorer la production dans des puits

Publications (3)

Publication Number Publication Date
EP1731709A2 EP1731709A2 (fr) 2006-12-13
EP1731709A3 EP1731709A3 (fr) 2007-04-11
EP1731709B1 true EP1731709B1 (fr) 2009-09-30

Family

ID=24346590

Family Applications (2)

Application Number Title Priority Date Filing Date
EP06076630A Expired - Lifetime EP1731709B1 (fr) 2000-06-01 2001-05-25 Procédé et système permettant d'effectuer des opérations et d'améliorer la production dans des puits
EP01941647A Expired - Lifetime EP1287230B1 (fr) 2000-06-01 2001-05-25 Procede et systeme permettant d'effectuer des operations et d'ameliorer la production dans des puits

Family Applications After (1)

Application Number Title Priority Date Filing Date
EP01941647A Expired - Lifetime EP1287230B1 (fr) 2000-06-01 2001-05-25 Procede et systeme permettant d'effectuer des operations et d'ameliorer la production dans des puits

Country Status (10)

Country Link
EP (2) EP1731709B1 (fr)
CN (2) CN1203325C (fr)
AU (1) AU781046B2 (fr)
CA (1) CA2379451C (fr)
DK (2) DK1731709T3 (fr)
MX (1) MXPA02001004A (fr)
NO (1) NO325161B1 (fr)
OA (1) OA11891A (fr)
RU (1) RU2272907C2 (fr)
WO (1) WO2001092675A2 (fr)

Families Citing this family (15)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US7385523B2 (en) * 2000-03-28 2008-06-10 Schlumberger Technology Corporation Apparatus and method for downhole well equipment and process management, identification, and operation
US6989764B2 (en) 2000-03-28 2006-01-24 Schlumberger Technology Corporation Apparatus and method for downhole well equipment and process management, identification, and actuation
US6915848B2 (en) 2002-07-30 2005-07-12 Schlumberger Technology Corporation Universal downhole tool control apparatus and methods
US6776240B2 (en) 2002-07-30 2004-08-17 Schlumberger Technology Corporation Downhole valve
US20070243113A1 (en) 2006-04-12 2007-10-18 Dileo Anthony Filter with memory, communication and concentration sensor
US8007568B2 (en) 2006-04-12 2011-08-30 Millipore Corporation Filter with memory, communication and pressure sensor
WO2008032194A2 (fr) 2006-09-15 2008-03-20 Schlumberger Technology B.V. Procédés et systèmes pour la diagraphie d'ouverture à l'aide de communication radiofréquence
US8157022B2 (en) * 2007-09-28 2012-04-17 Schlumberger Technology Corporation Apparatus string for use in a wellbore
US8584519B2 (en) * 2010-07-19 2013-11-19 Halliburton Energy Services, Inc. Communication through an enclosure of a line
GB201012175D0 (en) * 2010-07-20 2010-09-01 Metrol Tech Ltd Procedure and mechanisms
CN102841546B (zh) * 2011-06-24 2016-05-25 中国石油化工股份有限公司 一种井下控制系统，控制方法及其应用
CN104653159B (zh) * 2015-02-02 2017-02-22 中国石油集团渤海钻探工程有限公司 多级压裂智能控制系统
WO2018191820A1 (fr) * 2017-04-18 2018-10-25 Intelligent Wellhead Systems Inc. Système, appareil et procédé destinés à la détection d'outils filaires
WO2022146175A1 (fr) * 2020-12-30 2022-07-07 Общество С Ограниченной Ответственностью "Стройпромгрупп" Procédé de détermination de profondeur, de vitesse et de temps de séjour d'un tube de forage dans un puits
CN113294141A (zh) * 2021-05-24 2021-08-24 西安格威石油仪器有限公司 多通道并发式深度同步电缆测井方法

Family Cites Families (17)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3426850A (en) * 1966-06-20 1969-02-11 Exxon Production Research Co Method and apparatus for perforating in wells
US4656463A (en) * 1983-04-21 1987-04-07 Intelli-Tech Corporation LIMIS systems, devices and methods
US4698631A (en) * 1986-12-17 1987-10-06 Hughes Tool Company Surface acoustic wave pipe identification system
US4808925A (en) * 1987-11-19 1989-02-28 Halliburton Company Three magnet casing collar locator
US5202680A (en) * 1991-11-18 1993-04-13 Paul C. Koomey System for drill string tallying, tracking and service factor measurement
US5279366A (en) * 1992-09-01 1994-01-18 Scholes Patrick L Method for wireline operation depth control in cased wells
EP0601811B1 (fr) * 1992-12-07 1997-10-01 Akishima Laboratories (Mitsui Zosen) Inc. Système de mesure pendant le forage utilisant une vanne d'impulsion de pression pour la transmission de données
US5361838A (en) * 1993-11-01 1994-11-08 Halliburton Company Slick line casing and tubing joint locator apparatus and associated methods
US5429190A (en) * 1993-11-01 1995-07-04 Halliburton Company Slick line casing and tubing joint locator apparatus and associated methods
GB9408588D0 (en) * 1994-04-29 1994-06-22 Disys Corp Passive transponder
AU697762B2 (en) * 1995-03-03 1998-10-15 Halliburton Company Locator and setting tool and methods of use thereof
US5995449A (en) * 1995-10-20 1999-11-30 Baker Hughes Inc. Method and apparatus for improved communication in a wellbore utilizing acoustic signals
US5720345A (en) * 1996-02-05 1998-02-24 Applied Technologies Associates, Inc. Casing joint detector
US5626192A (en) * 1996-02-20 1997-05-06 Halliburton Energy Services, Inc. Coiled tubing joint locator and methods
US6025780A (en) * 1997-07-25 2000-02-15 Checkpoint Systems, Inc. RFID tags which are virtually activated and/or deactivated and apparatus and methods of using same in an electronic security system
US6333699B1 (en) 1998-08-28 2001-12-25 Marathon Oil Company Method and apparatus for determining position in a pipe
US6151961A (en) * 1999-03-08 2000-11-28 Schlumberger Technology Corporation Downhole depth correlation

Also Published As

Publication number Publication date
MXPA02001004A (es) 2002-08-12
DK1731709T3 (da) 2009-12-21
NO325161B1 (no) 2008-02-11
EP1731709A2 (fr) 2006-12-13
CN1203325C (zh) 2005-05-25
RU2272907C2 (ru) 2006-03-27
WO2001092675A3 (fr) 2002-06-06
NO20020499D0 (no) 2002-01-31
OA11891A (en) 2006-03-28
WO2001092675A2 (fr) 2001-12-06
CN100343482C (zh) 2007-10-17
CN1664309A (zh) 2005-09-07
NO20020499L (no) 2002-03-26
EP1287230A2 (fr) 2003-03-05
EP1287230A4 (fr) 2005-04-27
AU7498301A (en) 2001-12-11
CN1418317A (zh) 2003-05-14
DK1287230T3 (da) 2007-01-02
CA2379451A1 (fr) 2001-12-06
AU781046B2 (en) 2005-05-05
EP1731709A3 (fr) 2007-04-11
CA2379451C (fr) 2006-11-07
EP1287230B1 (fr) 2006-11-08

Similar Documents

Publication Publication Date Title
US7714741B2 (en) Method and system for performing operations and for improving production in wells
US6536524B1 (en) Method and system for performing a casing conveyed perforating process and other operations in wells
EP3420185B1 (fr) Système de transfert de différentiel
US8016036B2 (en) Tagging a formation for use in wellbore related operations
EP1731709B1 (fr) Procédé et système permettant d'effectuer des opérations et d'améliorer la production dans des puits
EP1274992B1 (fr) Appareil et procede pour equipement de fond de puits et gestion de processus, identification et actionnement
AU2001290675A1 (en) Method and system for perforating
EP2966258B1 (fr) Positionnement de profondeur au moyen de corrélation de rayon gamma et différentiel de paramètres de fond de trou
US11286756B2 (en) Slickline selective perforation system
EP1584783B1 (fr) Procédé de télémétrie dans un puits de forage
EP0647767A2 (fr) Procédé pour l'exécution de travaux de perforation dans un puits à l'aide d'un train de tubes de production
WO2009004336A1 (fr) Indicateur de position inertielle
SA01220406B1 (ar) طريقة وجهاز لإجراء العمليات ولتحسين الإنتاج في الابار

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

AC Divisional application: reference to earlier application

Ref document number: 1287230

Country of ref document: EP

Kind code of ref document: P

AK Designated contracting states

Kind code of ref document: A2

Designated state(s): DK FR GB NL

PUAL Search report despatched

Free format text: ORIGINAL CODE: 0009013

AK Designated contracting states

Kind code of ref document: A3

Designated state(s): DK FR GB NL

17P Request for examination filed

Effective date: 20071010

17Q First examination report despatched

Effective date: 20071116

AKX Designation fees paid

Designated state(s): DK FR GB NL

GRAP Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOSNIGR1

GRAS Grant fee paid

Free format text: ORIGINAL CODE: EPIDOSNIGR3

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

AC Divisional application: reference to earlier application

Ref document number: 1287230

Country of ref document: EP

Kind code of ref document: P

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): DK FR GB NL

REG Reference to a national code

Ref country code: GB

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: DK

Ref legal event code: T3

PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT

26N No opposition filed

Effective date: 20100701

REG Reference to a national code

Ref country code: FR

Ref legal event code: PLFP

Year of fee payment: 15

REG Reference to a national code

Ref country code: FR

Ref legal event code: PLFP

Year of fee payment: 16

REG Reference to a national code

Ref country code: FR

Ref legal event code: PLFP

Year of fee payment: 17

REG Reference to a national code

Ref country code: GB

Ref legal event code: 732E

Free format text: REGISTERED BETWEEN 20171116 AND 20171122

REG Reference to a national code

Ref country code: FR

Ref legal event code: PLFP

Year of fee payment: 18

REG Reference to a national code

Ref country code: NL

Ref legal event code: PD

Owner name: WEATHERFORD TECHNOLOGY HOLDINGS, LLC; US

Free format text: DETAILS ASSIGNMENT: CHANGE OF OWNER(S), ASSIGNMENT; FORMER OWNER NAME: MARATHON OIL COMPANY

Effective date: 20180703

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: NL

Payment date: 20200513

Year of fee payment: 20

Ref country code: DK

Payment date: 20200512

Year of fee payment: 20

Ref country code: FR

Payment date: 20200414

Year of fee payment: 20

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: GB

Payment date: 20200401

Year of fee payment: 20

REG Reference to a national code

Ref country code: NL

Ref legal event code: RC

Free format text: DETAILS LICENCE OR PLEDGE: RIGHT OF PLEDGE, ESTABLISHED

Name of requester: DEUTSCHE BANK TRUST COMPANY AMERICAS

Effective date: 20200723

REG Reference to a national code

Ref country code: GB

Ref legal event code: 732E

Free format text: REGISTERED BETWEEN 20200813 AND 20200819

REG Reference to a national code

Ref country code: GB

Ref legal event code: 732E

Free format text: REGISTERED BETWEEN 20201126 AND 20201202

REG Reference to a national code

Ref country code: NL

Ref legal event code: MK

Effective date: 20210524

REG Reference to a national code

Ref country code: DK

Ref legal event code: EUP

Expiry date: 20210525

REG Reference to a national code

Ref country code: GB

Ref legal event code: PE20

Expiry date: 20210524

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: GB

Free format text: LAPSE BECAUSE OF EXPIRATION OF PROTECTION

Effective date: 20210524