# US 7,746,076 B2 · Method for imaging subterranean formations > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 7,746,076 B2 - Document ID: US7746076B2 - Status: Granted - Kind: B2 - Application number: 12/476,670 - Filed: 2009-06-02 - Published: 2009-09-24 - Granted: 2010-06-29 - Earliest claimed: 2003-11-05 - Assignees: Shell Oil Company - Inventors: Richard Martin Ostermeier; Teruhiko Hagiwara; Erik Jan Banning - Web page: https://patentgrep.com/patent/US7746076B2 ## CPC - G01V 3/28: using induction coils - G01V 3/38: Processing data, e.g. for analysis, for interpretation, for correction - G01V: GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS (means for indicating the location of accidentally buried, e.g. snow-buried, persons A63B29/02) ## Abstract A method for using a tool in a wellbore in a formation to predict an anomaly in the formation ahead of the device, the tool comprising a transmitter for transmitting electromagnetic signals through the formation and a receiver for detecting response signals. the method comprises a) bringing the tool to a first position inside the wellbore; b) energizing the transmitter to propagate a transient electromagnetic signal into the formation; c) detecting a response signal that has propagated through the formation as a result of the transient signal in step (b); d) calculating a derived quantity for the formation as a function of time based on the detected response signal for the formation; e) plotting the derived quantity for the formation against time; f) moving the tool to at least one other position within the wellbore and repeating steps (b) to (e); g) predicting an anomaly in the formation. ## Claims ### Claim 1 A method for using a tool in a wellbore in a formation to predict an anomaly in the formation ahead of the device, the tool comprising a transmitter for transmitting electromagnetic signals through the formation and a receiver for detecting response signals, the method comprising the steps of: a) bringing the tool to a first position inside the wellbore; b) energizing the transmitter to propagate a transient electromagnetic signal into the formation; c) detecting a response signal that has propagated through the formation as a result of the transient signal in step (b); d) calculating a derived quantity for the formation as a function of time based on the detected response signal for the formation; e) plotting the derived quantity for the formation against time; f) moving the tool to at least one other position within the wellbore and repeating steps (b) to (e); and g) predicting an anomaly in the formation ahead of the device by comparing the plots generated in each step e). ### Claim 2 (depends on 1) The method of claim 1 wherein step g) further includes identifying one or more inflection points on each plotted derived quantity and fitting a curve to the one or more inflection points. ### Claim 3 (depends on 1) The method of claim 1 wherein the derived quantity is one of apparent conductivity and apparent resistivity and apparent dip angle and apparent azimuth angle. ### Claim 4 (depends on 1) The method of claim 1 wherein for each position of the tool in the wellbore a distance is determined from the tool to the anomaly by determining a time in which the derived quantity begins to deviate from the corresponding one of apparent conductivity and apparent resistivity of formation in which the device is located. ### Claim 5 (depends on 1) The method of claim 1 wherein step c) includes detecting the response signal for a time period that is sufficiently long to allow have the derived quantity to reach an asymptotic value. ### Claim 6 (depends on 1) The method of claim 1 wherein the electromagnetic signal is transmitted in the direction of the anomaly. ### Claim 7 (depends on 1) The method of claim 1 wherein the device comprises a logging tool. ### Claim 8 (depends on 7) The method of claim 7 wherein the device is provided in a measurement-while-drilling or logging-while-drilling section of a drill string located uphole relative to a drill bit. ### Claim 9 A method for using a tool in a wellbore in a formation to predict an anomaly in the formation ahead of the device, the tool comprising a transmitter for transmitting electromagnetic signals through the formation and a receiver for detecting response signals, the method comprising the steps of: a) bringing the tool to a first position inside the wellbore; b) energizing the transmitter to propagate a transient electromagnetic signal into the formation; c) detecting a response signal that has propagated through the formation as a result of the transient signal in step (b); d) calculating a derived quantity for the formation as a function of time based on the detected response signal for the formation; e) plotting the derived quantity for the formation against time; f) moving the tool to at least one other position within the wellbore and repeating steps (b) to (e); and g) predicting an anomaly in the formation ahead of the device by plotting the derived quantity for the formation calculated in respect of the tool at the at least two positions in a plot having logging depth and time as its axes and fitting at least one curve to the plots of the derived quantity for said at least two positions. ### Claim 10 (depends on 9) The method of claim 9 wherein step g) further includes identifying one or more inflection points on each plotted derived quantity and fitting a curve to the one or more inflection points. ### Claim 11 (depends on 9) The method of claim 9 wherein the derived quantity is one of apparent conductivity and apparent resistivity and apparent dip angle and apparent azimuth angle. ### Claim 12 (depends on 9) The method of claim 9 wherein for each position of the tool in the wellbore a distance is determined from the tool to the anomaly by determining a time in which the derived quantity begins to deviate from the corresponding one of apparent conductivity and apparent resistivity of formation in which the device is located. ### Claim 13 (depends on 9) The method of claim 9 wherein step c) includes detecting the response signal for a time period that is sufficiently long to allow have the derived quantity to reach an asymptotic value. ### Claim 14 (depends on 9) The method of claim 9 wherein the electromagnetic signal is transmitted in the direction of the anomaly. ### Claim 15 (depends on 9) The method of claim 9 wherein the device comprises a logging tool. ### Claim 16 (depends on 15) The method of claim 15 wherein the device is provided in a measurement-while-drilling or logging-while-drilling section of a drill string located uphole relative to a drill bit.