Apparatus, Tool and Method for Look-Ahead Advance Formation Evaluation which investigates the formation or formation characteristic in advance of the drill-bit before the formation or formation feature of interest has been penetrated or traversed. A closed-loop real-time look-ahead formation evaluat
Apparatus, Tool and Method for Look-Ahead Advance Formation Evaluation which investigates the formation or formation characteristic in advance of the drill-bit before the formation or formation feature of interest has been penetrated or traversed. A closed-loop real-time look-ahead formation evaluation tool which provides acoustic and/or electro-magnetic formation data beyond the drill-bit using a novel angular sensor orientation which also allows for optimized signal propagation and signal returns according to an axial plane and vertical depth.
대표청구항▼
1. A look ahead tool comprising a tool body with means for attaching the tool body for rotation directly or indirectly to drill-bit for axial movement along a well passage comprising: at least one housing supporting at least one acoustic source and an acoustic receiver or integrated transducer direc
1. A look ahead tool comprising a tool body with means for attaching the tool body for rotation directly or indirectly to drill-bit for axial movement along a well passage comprising: at least one housing supporting at least one acoustic source and an acoustic receiver or integrated transducer directed outwardly toward a downhole end of said tool body andprojecting at an angle (φ) of at least 0.25° and less than 89.75° relative to a central axis of the tool body wherein the source or the transducer transmits sound and wherein the receiver or transducer receives acoustic signature velocities from a formation; andat least one microprocessor for processing said acoustic signature velocities using said at least one acoustic source, receiver or transducer to increase hydrocarbon recovery by optimizing wellbore trajectory based on formation data acquired by said acoustic source and said receiver or said transducer before the formation has been penetrated by the drill-bitwherein said at least one acoustic source, acoustic receiver or integrated transducer are received within said housing of said tool body, said housing having an open mouthwherein said housing comprises a protective covering or protective layers made of a hardened material. 2. A tool as claimed in claim 1, wherein said at least one acoustic source, receiver or transducer is provided with an outer surface that is concave, or convex, or planar. 3. A tool as claimed in 1 wherein an electro-magnetic source and said receiver or integrated transducer send and receive electro-magnetic data to and from the formation ahead of a drill-bit, and said data is processed by said microprocessor. 4. A tool as claimed in claim 1 further comprising: a first tool body to investigate a formation ahead of the drill-bit, and a second tool body to stabilize the tool during drilling. 5. A tool as claimed in claim 1 further comprising: a microprocessor controller adapted to receive data based on acoustic signature velocities recognized by said receivers or said transducers, and detect a formation or formation feature and control a directional tool in response to acquired acoustic data to maximize wellbore footage drilled in productive reservoir zones. 6. A tool as claimed in claim 1 further comprising: a plurality of said sources, said receivers or said transducers directed outwardly of said tool body or separately housed and placed along the drill-string in separate tool bodies. 7. A tool as claimed in claim 1 wherein one of acoustic source, receiver or transducer is housed in a drill-bit. 8. A tool as claimed in claim 1 further comprising: communication means for communicating said acoustic data or electromagnetic and control signals with the microprocessor, and a surface decoder and user interface in real-time to optimize performance. 9. A tool as claimed in claim 1 wherein the means for attaching the tool body comprises a screw thread on the tool body to engage the drill bit, a directional control system, drill collar or coiled tubing. 10. A look ahead tool comprising a tool body with means for attaching the tool body for rotation directly or indirectly to drill-bit for axial movement along a well passage comprising: at least one housing supporting at least one acoustic source and an acoustic receiver or integrated transducer directed outwardly toward a downhole end of said tool body andprojecting at an angle (φ) of at least 0.25° and less than 89.75° relative to a central axis of the tool body wherein the source or the transducer transmits sound and wherein the receiver or transducer receives acoustic signature velocities from a formation; andat least one microprocessor for processing said acoustic signature velocities using said at least one acoustic source, receiver or transducer to increase hydrocarbon recovery by optimizing wellbore trajectory based on formation data acquired by said acoustic source and said receiver or said transducer before the formation has been penetrated by the drill-bit and wherein said tool body is configured with a rotary steerable system with a wall contact member at an end. 11. A look ahead tool comprising a tool body with means for attaching the tool body for rotation directly or indirectly to drill-bit for axial movement along a well passage comprising: at least one housing supporting at least one acoustic source and an acoustic receiver or integrated transducer directed outwardly toward a downhole end of said tool body andprojecting at an angle (φ) of at least 0.25° and less than 89.75° relative to a central axis of the tool body wherein the source or the transducer transmits sound and wherein the receiver or transducer receives acoustic signature velocities from a formation; andat least one microprocessor for processing said acoustic signature velocities using said at least one acoustic source, receiver or transducer to increase hydrocarbon recovery by optimizing wellbore trajectory based on formation data acquired by said acoustic source and said receiver or said transducer before the formation has been penetrated by the drill-bit wherein the said tool body includes a downhole wall contact member to form one of a roller reamer, an expandable underreamer, a pressure containment device, and a measurement device. 12. A look ahead tool comprising a tool body with means for attaching the tool body for rotation directly or indirectly to drill-bit for axial movement along a well passage comprising: at least one housing supporting at least one acoustic source and an acoustic receiver or integrated transducer directed outwardly toward a downhole end of said tool body andprojecting at an angle (φ) of at least 0.25° and less than 89.75° relative to a central axis of the tool body wherein the source or the transducer transmits sound and wherein the receiver or transducer receives acoustic signature velocities from a formation; andat least one microprocessor for processing said acoustic signature velocities using said at least one acoustic source, receiver or transducer to increase hydrocarbon recovery by optimizing wellbore trajectory based on formation data acquired by said acoustic source and said receiver or said transducer before the formation has been penetrated by the drill-bit;wherein said tool body is provided with an internal keyway leading to a source of power communications inside or outside the tool and capable of sending an alert signal to a user. 13. An automated method of operating a look ahead tool to acquire formation data and optimally place a wellbore or tubular or sand screen, or drilling, completion or production system or any downhole device comprising: locating the tool being supported on a drill-bit and drill-string and a surface interface controls and exchanges data with the drill string during the formation evaluation operation according to a program to deliver a desired wellbore placement andactivating an acoustic source, receiver or transducer to send and receive formation data,rotating the tool and moving the tool axially along the borehole on the drill-bit, receiving data from the receiver anddetecting a formation feature:comparing the formation feature with a pre-programmed wellbore trajectory andautomatically alerting an operator or changing the conditions of a directional control system in response thereto andcontinuing the formation evaluation until an optimal wellbore placement is achieved using logic programming to diagnose and correct common errors or failures. 14. An automated method of operating a look ahead tool to optimally place a wellbore or tubular or sand screen, or drilling, completion or production system or any downhole device comprising: locating the tool on a drill-bit or support in a wellbore;activating an acoustic source, receiver or transducer to send and receive formation datarotating the tool and moving the tool axially along the borehole on the drill-bit or support receiving data from the receiver andcontinuing the formation evaluation until an optimal wellbore placement is achieved using logic programming to diagnose and correct common errors or failures;wherein formations are detected as rock types, earthen formations or lithologies with a feature of interest including one or more of porosity or a change in porosity, permeability or a change in permeability, an oil zone, a gas zone, a water zone, a fracture, a fault, a dip, a bed, a vugular formation, an anticline, a syncline or a trap. 15. An automated method of operating a look ahead tool to optimally place a wellbore or tubular or sand screen, or drilling, completion or production system or any downhole device comprising: locating the tool on a drill-bit in a wellbore;activating an acoustic source, receiver or transducer to send and receive formation datarotating the tool and moving the tool axially along the borehole on the drill-bit, receiving data from the receiver andcontinuing the formation evaluation until an optimal wellbore placement is achieved using logic programming to diagnose and correct common errors or failureswherein said tool detects a pore pressure regression and anticipates a drilling fluid loss before drilling fluid enters the formation. 16. An automated method of operating a look ahead tool to optimally place a wellbore or tubular or sand screen, or drilling, completion or production system or any downhole device comprising: locating the tool on a drill-bit in a wellbore;activating an acoustic source, receiver or transducer to send and receive formation data.rotating the tool and moving the tool axially along the borehole on the drill-bit, receiving data from the receiver andcontinuing the formation evaluation until an optimal wellbore placement is achieved using logic programming to diagnose and correct common errors or failures;wherein said tool body is treated with a surface treatment to actively send or receive echo pulses rendering it a sensing zone. 17. An automated method of operating a look ahead tool to optimally place a wellbore or tubular or sand screen, or drilling, completion or production system or any downhole device comprising: locating the tool on a drill-bit in a wellbore;activating an acoustic source, receiver or transducer to send and receive formation datarotating the tool and moving the tool axially along the borehole on the drill-bit, receiving data from the receiver andcontinuing the formation evaluation until an optimal wellbore placement is achieved using logic programming to diagnose and correct common errors or failures;wherein the tool detects a highly pressurized zone and anticipates a kick or influx before entering a wellbore. 18. An automated method of operating a look ahead tool to optimally place a wellbore or tubular or sand screen, or drilling, completion or production system or any downhole device comprising: locating the tool on a drill-bit or support in a wellbore;activating an acoustic source, receiver or transducer to send and receive formation datarotating the tool and moving the tool axially along the borehole on the drill-bit or support, receiving data from the receiver andcontinuing the formation evaluation until an optimal wellbore placement is achieved using logic programming to diagnose and correct common errors or failures;wherein the acoustic source, receiver or transducer is connected to a processor and a directional control system;further comprising: performing a diagnostic and troubleshooting procedure. 19. An automated method of operating a look ahead tool to optimally place a wellbore or tubular or sand screen, or drilling, completion or production system or any downhole device comprising: locating the tool on a drill-bit or support in a wellbore;activating an acoustic source, receiver or transducer to send and receive formation dataRotating the tool and moving the tool axially along the borehole on the drill-bit or support, receiving data from the receiver andcontinuing the formation evaluation until an optimal wellbore placement is achieved using logic programming to diagnose and correct common errors or failures;and establishing background noise and establishing minimum noise values to exclude from operational calculations.
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