Patents by Inventor William Lesso
William Lesso has filed for patents to protect the following inventions. This listing includes patent applications that are pending as well as patents that have already been granted by the United States Patent and Trademark Office (USPTO).
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Patent number: 10190407Abstract: A method for evaluating inflow or outflow in a subterranean wellbore includes acquiring first and second axially spaced pressure measurements in the wellbore. The pressure measurements may then be processed to obtain an interval density of drilling fluid between the measurement locations. A tool string including a large number of axially spaced pressure sensors (e.g., four or more or even six or more) electronically coupled with a surface processor via wired drill pipe may be used to obtain a plurality of interval densities corresponding to various wellbore intervals. The interval density may be measured during static conditions or while drilling and may be further processed to compute a density of an inflow constituent in the annulus. Changes in the computed interval density with time may be used as an indicator of either an inflow event or an outflow event.Type: GrantFiled: June 22, 2016Date of Patent: January 29, 2019Assignee: SCHLUMBERGER TECHNOLOGY CORPORATIONInventors: John Rasmus, William Lesso, John James
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Patent number: 9765583Abstract: A method for estimating equivalent top of fluid level or a theoretical surface annular back pressure in a subterranean wellbore includes acquiring first and second axially spaced pressure measurements in the wellbore. The pressure measurements may then be processed to compute the equivalent top of fluid level and/or theoretical surface annular back pressure of drilling fluid between the measurement locations. A tool string including a large number of axially spaced pressure sensors (e.g., four or more or even six or more) electronically coupled with a surface processor via wired drill pipe may be used to obtain a plurality of values corresponding to various wellbore intervals. The equivalent top of fluid level and/or theoretical surface annular back pressures may be used in automated managed pressure drilling operations.Type: GrantFiled: August 6, 2015Date of Patent: September 19, 2017Assignee: SCHLUMBERGER TECHNOLOGY CORPORATIONInventors: John Rasmus, William Lesso, John James
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Publication number: 20160376886Abstract: A method for evaluating inflow or outflow in a subterranean wellbore includes acquiring first and second axially spaced pressure measurements in the wellbore. The pressure measurements may then be processed to obtain an interval density of drilling fluid between the measurement locations. A tool string including a large number of axially spaced pressure sensors (e.g., four or more or even six or more) electronically coupled with a surface processor via wired drill pipe may be used to obtain a plurality of interval densities corresponding to various wellbore intervals. The interval density may be measured during static conditions or while drilling and may be further processed to compute a density of an inflow constituent in the annulus. Changes in the computed interval density with time may be used as an indicator of either an inflow event or an outflow event.Type: ApplicationFiled: June 22, 2016Publication date: December 29, 2016Inventors: John Rasmus, William Lesso, John James
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Patent number: 9404327Abstract: A method identifying a wellbore volume change while drilling a subterranean wellbore includes acquiring first and second axially spaced pressure measurements in the wellbore. The wellbore volume change may include, for example, a borehole washout or a borehole pack-off. The pressure measurements may then be processed to obtain an interval density of drilling fluid between the measurement locations. A tool string including a large number of axially spaced pressure sensors (e.g., four or more or even six or more) electronically coupled with a surface processor via wired drill pipe may be used to obtain a plurality of interval densities corresponding to various wellbore intervals. The interval densities may be measured while drilling and may be further evaluated as an indicator of a wellbore volume change.Type: GrantFiled: August 14, 2012Date of Patent: August 2, 2016Assignee: SCHLUMBERGER TECHNOLOGY CORPORATIONInventors: John Rasmus, William Lesso, John James
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Patent number: 9394783Abstract: A method for evaluating inflow or outflow in a subterranean wellbore includes acquiring first and second axially spaced pressure measurements in the wellbore. The pressure measurements may then be processed to obtain an interval density of drilling fluid between the measurement locations. A tool string including a large number of axially spaced pressure sensors (e.g., four or more or even six or more) electronically coupled with a surface processor via wired drill pipe may be used to obtain a plurality of interval densities corresponding to various wellbore intervals. The interval density may be measured during static conditions or while drilling and may be further processed to compute a density of an inflow constituent in the annulus. Changes in the computed interval density with time may be used as an indicator of either an inflow event or an outflow event.Type: GrantFiled: August 14, 2012Date of Patent: July 19, 2016Assignee: Schlumberger Technology CorporationInventors: John Rasmus, William Lesso, John James
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Publication number: 20160002991Abstract: A method for estimating equivalent top of fluid level or a theoretical surface annular back pressure in a subterranean wellbore includes acquiring first and second axially spaced pressure measurements in the wellbore. The pressure measurements may then be processed to compute the equivalent top of fluid level and/or theoretical surface annular back pressure of drilling fluid between the measurement locations. A tool string including a large number of axially spaced pressure sensors (e.g., four or more or even six or more) electronically coupled with a surface processor via wired drill pipe may be used to obtain a plurality of values corresponding to various wellbore intervals. The equivalent top of fluid level and/or theoretical surface annular back pressures may be used in automated managed pressure drilling operations.Type: ApplicationFiled: August 6, 2015Publication date: January 7, 2016Inventors: John Rasmus, William Lesso, John James
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Patent number: 9228430Abstract: A method evaluating a cuttings density while drilling a subterranean wellbore includes acquiring first and second axially spaced pressure measurements in the wellbore. The pressure measurements may then be processed to obtain an interval density of drilling fluid between the measurement locations. A tool string including a large number of axially spaced pressure sensors (e.g., four or more or even six or more) electronically coupled with a surface processor via wired drill pipe may be used to obtain a plurality of interval densities corresponding to various wellbore intervals. The interval density may be measured while drilling and may be further processed to compute a cuttings density in the annulus. Moreover, changes in the computed interval density with time while drilling may be used as an indicator of a change in cuttings density.Type: GrantFiled: August 14, 2012Date of Patent: January 5, 2016Assignee: Schlumberger Technology CorporationInventors: John Rasmus, William Lesso, John James, Edward M. Tollefsen, Scott Paul, Amanda L. Weber, Marcus Turner
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Patent number: 9134451Abstract: A method for estimating equivalent top of fluid level or a theoretical surface annular back pressure in a subterranean wellbore includes acquiring first and second axially spaced pressure measurements in the wellbore. The pressure measurements may then be processed to compute the equivalent top of fluid level and/or theoretical surface annular back pressure of drilling fluid between the measurement locations. A tool string including a large number of axially spaced pressure sensors (e.g., four or more or even six or more) electronically coupled with a surface processor via wired drill pipe may be used to obtain a plurality of values corresponding to various wellbore intervals. The equivalent top of fluid level and/or theoretical surface annular back pressures may be used in automated managed pressure drilling operations.Type: GrantFiled: August 14, 2012Date of Patent: September 15, 2015Assignee: Schlumberger Technology CorporationInventors: John Rasmus, William Lesso, John James
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Patent number: 8857510Abstract: A system and a method determine movement of a drilling component, such as, for example, a tool, a drill bit or other wellbore device, within a wellbore. The system and method may process information obtained from the wellbore by using, for example, a numerical processing algorithm. The information may be data acquired during drilling of the wellbore. Rig surface data recording systems may track the position of the drill bit, the BHA and/or other component of the drill string during the time the component is within the wellbore. Downhole measuring devices may record data at various positions along the BHA and above the drill bit as a function of time.Type: GrantFiled: April 5, 2010Date of Patent: October 14, 2014Assignee: Schlumberger Technology CorporationInventors: John Rasmus, John James, William Lesso
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Patent number: 8851178Abstract: A method of fracturing a formation while drilling a wellbore. The method includes providing a bottomhole assembly (“BHA”) having a reamer positioned above a pilot hole assembly, connecting the BHA to a drill string, actuating the BHA to drill a first wellbore section with the reamer and to drill a pilot hole with the pilot hole assembly, hydraulically sealing the pilot hole from the first wellbore section, and fracturing the formation proximate the pilot hole.Type: GrantFiled: October 12, 2007Date of Patent: October 7, 2014Assignee: Schlumberger Technology CorporationInventors: William Lesso, Robert Utter
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Publication number: 20130090855Abstract: A method for evaluating inflow or outflow in a subterranean wellbore includes acquiring first and second axially spaced pressure measurements in the wellbore. The pressure measurements may then be processed to obtain an interval density of drilling fluid between the measurement locations. A tool string including a large number of axially spaced pressure sensors (e.g., four or more or even six or more) electronically coupled with a surface processor via wired drill pipe may be used to obtain a plurality of interval densities corresponding to various wellbore intervals. The interval density may be measured during static conditions or while drilling and may be further processed to compute a density of an inflow constituent in the annulus. Changes in the computed interval density with time may be used as an indicator of either an inflow event or an outflow event.Type: ApplicationFiled: August 14, 2012Publication date: April 11, 2013Inventors: John Rasmus, William Lesso, John James
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Publication number: 20130090854Abstract: A method identifying a wellbore volume change while drilling a subterranean wellbore includes acquiring first and second axially spaced pressure measurements in the wellbore. The wellbore volume change may include, for example, a borehole washout or a borehole pack-off. The pressure measurements may then be processed to obtain an interval density of drilling fluid between the measurement locations. A tool string including a large number of axially spaced pressure sensors (e.g., four or more or even six or more) electronically coupled with a surface processor via wired drill pipe may be used to obtain a plurality of interval densities corresponding to various wellbore intervals. The interval densities may be measured while drilling and may be further evaluated as an indicator of a wellbore volume change.Type: ApplicationFiled: August 14, 2012Publication date: April 11, 2013Inventors: John Rasmus, William Lesso, John James
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Publication number: 20130054146Abstract: A method evaluating a cuttings density while drilling a subterranean wellbore includes acquiring first and second axially spaced pressure measurements in the wellbore. The pressure measurements may then be processed to obtain an interval density of drilling fluid between the measurement locations. A tool string including a large number of axially spaced pressure sensors (e.g., four or more or even six or more) electronically coupled with a surface processor via wired drill pipe may be used to obtain a plurality of interval densities corresponding to various wellbore intervals. The interval density may be measured while drilling and may be further processed to compute a cuttings density in the annulus. Moreover, changes in the computed interval density with time while drilling may be used as an indicator of a change in cuttings density.Type: ApplicationFiled: August 14, 2012Publication date: February 28, 2013Inventors: John Rasmus, William Lesso, John James, Edward M. Tollefsen, Scott Paul, Amanda L. Weber, Marcus Turner
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Publication number: 20130047696Abstract: A method for estimating equivalent top of fluid level or a theoretical surface annular back pressure in a subterranean wellbore includes acquiring first and second axially spaced pressure measurements in the wellbore. The pressure measurements may then be processed to compute the equivalent top of fluid level and/or theoretical surface annular back pressure of drilling fluid between the measurement locations. A tool string including a large number of axially spaced pressure sensors (e.g., four or more or even six or more) electronically coupled with a surface processor via wired drill pipe may be used to obtain a plurality of values corresponding to various wellbore intervals. The equivalent top of fluid level and/or theoretical surface annular back pressures may be used in automated managed pressure drilling operations.Type: ApplicationFiled: August 14, 2012Publication date: February 28, 2013Inventors: John Rasmus, William Lesso, John James
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Publication number: 20130048380Abstract: A method for estimating one or more interval densities in a subterranean wellbore includes acquiring first and second axially spaced pressure measurements in the wellbore. The pressure measurements may then be processed to obtain an interval density of drilling fluid between the measurement locations. A tool string including a large number of axially spaced pressure sensors (e.g., four or more or even six or more) electronically coupled with a surface processor via wired drill pipe may be used to obtain a plurality of interval densities corresponding to various wellbore intervals.Type: ApplicationFiled: August 14, 2012Publication date: February 28, 2013Inventors: John Rasmus, William Lesso, John James, Edward M. Tollefsen, Scott Paul, Amanda L. Weber, Marcus Turner, Paul Bolchover
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Patent number: 8245775Abstract: A subpart of a drill string is described having an outer circumferential surface which is contoured and adapted to engage the wall of the borehole with a small angle of attack while exerting during rotary drilling operations an compacting pressure on mud cake and/or cuttings present in the annulus between the drill string and the borehole.Type: GrantFiled: August 30, 2010Date of Patent: August 21, 2012Assignee: Schlumberger Technology CorporationInventors: Iain Cooper, Claude Vercaemer, William Lesso, Benjamin Peter Jeffryes, Michael Charles Sheppard
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Publication number: 20100319998Abstract: A subpart of a drill string is described having an outer circumferential surface which is contoured and adapted to engage the wall of the borehole with a small angle of attack while exerting during rotary drilling operations an compacting pressure on mud cake and/or cuttings present in the annulus between the drill string and the borehole.Type: ApplicationFiled: August 30, 2010Publication date: December 23, 2010Inventors: Iain Cooper, Claude Vercaemer, William Lesso, Benjamin Peter Jeffryes, Michael Charles Sheppard
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Publication number: 20100282512Abstract: A system and a method determine movement of a drilling component, such as, for example, a tool, a drill bit or other wellbore device, within a wellbore. The system and method may process information obtained from the wellbore by using, for example, a numerical processing algorithm. The information may be data acquired during drilling of the wellbore. Rig surface data recording systems may track the position of the drill bit, the BHA and/or other component of the drill string during the time the component is within the wellbore. Downhole measuring devices may record data at various positions along the BHA and above the drill bit as a function of time.Type: ApplicationFiled: April 5, 2010Publication date: November 11, 2010Inventors: John Rasmus, John James, William Lesso
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Patent number: 7810559Abstract: A subpart of a drill string is described having an outer circumferential surface which is contoured and adapted to engage the wall of the borehole with a small angle of attack while exerting during rotary drilling operations an compacting pressure on mud cake and/or cuttings present in the annulus between the drill string and the borehole.Type: GrantFiled: November 25, 2008Date of Patent: October 12, 2010Assignee: Schlumberger Technology CorporationInventors: Iain Cooper, Claude Vercaemer, William Lesso, Benjamin Peter Jeffryes, Michael Charles Sheppard
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Publication number: 20090095474Abstract: A method of fracturing a formation while drilling a wellbore includes the steps of: providing a bottomhole assembly (“BHA”) having a reamer positioned above a pilot hole assembly; connecting the BHA to a drill string; actuating the BHA to drill a first wellbore section with the reamer and to drill a pilot hole with the pilot hole assembly; hydraulically sealing the pilot hole from the first wellbore section; and fracturing the formation proximate the pilot hole.Type: ApplicationFiled: October 12, 2007Publication date: April 16, 2009Inventors: William Lesso, Robert Utter