Bottom Hole Pressure Patents (Class 166/250.07)
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Publication number: 20040099443Abstract: A formation test tool and methods are described that enable sampling and measurements of parameters of fluids contained in a borehole while reducing the time required for taking such samples and measurements and reducing the risk of formation damage due to sampling induced pressure spikes. The tool has a quick response control system for controlling a fluid transfer device in response to fluid pressure near a sampling port.Type: ApplicationFiled: July 22, 2003Publication date: May 27, 2004Applicant: Baker Hughes, IncorporatedInventors: Matthias Meister, Sven Krueger
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Patent number: 6729396Abstract: A coal formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. An average temperature and/or pressure within the formation may be controlled to inhibit production of hydrocarbons that have carbon numbers greater than 25. A small amount of hydrocarbons having carbon numbers greater than 25 may be entrained in vapor produced from the formation.Type: GrantFiled: April 24, 2001Date of Patent: May 4, 2004Assignee: Shell Oil CompanyInventors: Harold J. Vinegar, Scott Lee Wellington, Eric Pierre de Rouffignac, John Michael Karanikas, Ilya Emil Berchenko, George Leo Stegemeier, Etuan Zhang, Thomas David Fowler, Robert Charles Ryan
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Patent number: 6722429Abstract: A hydrocarbon containing formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. An unpyrolyzed section may be left between two substantially pyrolyzed sections to inhibit subsidence of the formation.Type: GrantFiled: April 24, 2001Date of Patent: April 20, 2004Assignee: Shell Oil CompanyInventors: Eric Pierre de Rouffignac, Harold J. Vinegar, Scott Lee Wellington, Ilya Emil Berchenko, George Leo Stegemeier, Kevin Albert Maher, Etuan Zhang, Gordon Thomas Shahin, Jr., Thomas David Fowler, Robert Charles Ryan
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Patent number: 6708758Abstract: A coal formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. An unpyrolyzed section may be left between two substantially pyrolyzed sections to inhibit subsidence of the formation.Type: GrantFiled: April 24, 2001Date of Patent: March 23, 2004Assignee: Shell Oil CompanyInventors: Eric Pierre de Rouffignac, Harold J. Vinegar, Scott Lee Wellington, John Michael Karanikas, Ilya Emil Berchenko, George Leo Stegemeier, Kevin Albert Maher, Etuan Zhang, Thomas David Fowler, Robert Charles Ryan
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Publication number: 20040050588Abstract: An apparatus and method for determining at least one downhole formation property is disclosed. The apparatus includes a probe and a pretest piston positionable in fluid communication with the formation, and a series of flowlines pressure gauges, and valves configured to selectively draw into the apparatus for measurement of one of formation fluid and mud. The method includes performing a first pretest to determine an estimated formation parameter; using the first pretest to design a second pretest and generate refined formation parameters whereby formation properties may be estimated.Type: ApplicationFiled: September 9, 2002Publication date: March 18, 2004Inventors: Jean-Marc Follini, Julian Pop
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Patent number: 6705398Abstract: A method for assessing the fracture pressure closure is proposed. This method includes first injecting a fluid into the formation at a first generally constant rate Q to create a fracture, and then, dropping the pumping rate to significantly smaller feed rate q so that the volume of the fracture becomes constant, in other words. As the fracture volume becomes constant at equilibrium, the well is shut-in. The wellbore pressure is monitored and the closure pressure is determined from the analysis of the wellbore pressure using a time-function of the dimensionless “shut-in” time, defined as the ratio of time since shutting to pumping time. This method provides a way of estimating the friction component of the monitored wellbore pressure due to the fracture tortuosity and friction. It is applicable to the art of fracturing subterranean formations and more particularly to the process of designing and analyzing stimulation treatments.Type: GrantFiled: June 24, 2002Date of Patent: March 16, 2004Assignee: Schlumberger Technology CorporationInventor: Xiaowei Weng
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Publication number: 20040045706Abstract: An apparatus and method for determining at least one downhole formation property is disclosed. The apparatus includes a pretest piston positionable in fluid communication with the formation, and a series of flowlines pressure gauges, and valves configured to selectively draw into the apparatus for measurement of one of formation fluid and mud. The method includes performing a first pretest to determine an estimated formation parameter; using the first pretest to design a second pretest and generate refined formation parameters whereby formation properties may be estimated.Type: ApplicationFiled: May 9, 2003Publication date: March 11, 2004Inventors: Julian Pop, Jean-Marc Follini, Jean-Michel Hache
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Method and Apparatus for Determinining the Temperature of Subterranean Wells Using Fiber Optic Cable
Publication number: 20040040705Abstract: Methods and apparatuses to determine the temperature profile of a pressurized wellbore using a fiber optic cable and an anchor are disclosed. Furthermore, a pressurized wellhead spool that couples to a standard Christmas tree structure on a well head to facilitate the injection of fiber optic cable into an oil and gas well is disclosed. The wellhead spool is portable and may be connected to fiber optic cable already located at the site, for quick connection to on-site instrumentation. A method of using the apparatuses disclosed to measure wellbore temperature at multiple depths of investigation is also disclosed.Type: ApplicationFiled: March 21, 2003Publication date: March 4, 2004Applicant: Sensor Highway LimitedInventor: Gary O. Harkins -
Publication number: 20040035577Abstract: This invention comprises the use of a variable orifice valve as a flow controller and flow meter. Pressure measurements are taken upstream and downstream of the variable orifice valve by way of a differential pressure measurement mechanism. The differential pressure measurement mechanism may comprise two separate absolute pressure measurement devices or a single differential pressure measurement device. Flow rate through the valve is determined from the pressure drop across the valve. In wellbores having multiple zones, a variable orifice valve together with a differential pressure measurement mechanism may be deployed for each zone. The flow rate through each of the zones and at the surface can then be monitored and controlled.Type: ApplicationFiled: August 20, 2003Publication date: February 26, 2004Inventors: Terizhandur S. Ramakrishnan, Gary M. Oddie, Sam Smonian
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Patent number: 6695052Abstract: An electric submersible pumping system having a downhole gauge section. The electric submersible pumping system comprises a submersible motor powered by a submersible pump. The submersible pump may be located below the submersible motor when in operation, while the downhole gauge section is disposed above the submersible motor. A power cable is coupled to the submersible motor through the downhole gauge section.Type: GrantFiled: January 8, 2002Date of Patent: February 24, 2004Assignee: Schlumberger Technology CorporationInventors: Todd M. Branstetter, Kevin T. Scarsdale, Lee S. Kobylinski, Nolan D. Wanner, John Pursell
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Publication number: 20040026125Abstract: A method and apparatus for of determining a formation parameter of interest. The method includes placing a tool into communication with the formation to test the formation, determining a first formation characteristic during a first test portion, initiating a second test portion, the second test portion having test parameters determined at least in part by the determinations made during the first test portion, determining a second formation characteristic during the second test portion, and determining the formation parameter from one of the first formation characteristic and the second formation characteristic. The apparatus includes a draw down unit and a control system for closed loop control of the draw down unit. A microprocessor in the control system processes signals from a sensor in the draw down unit to determine formation characteristics and to determine test parameters for subsequent test portions.Type: ApplicationFiled: April 25, 2003Publication date: February 12, 2004Applicant: Baker Hughes IncorporatedInventors: Matthias Meister, Jaedong Lee, Sven Krueger, Eick Niemeyer
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Patent number: 6675914Abstract: The pressure reading tool includes a housing with an interior chamber and an orifice extending from the chamber to the exterior of the housing. A pulse member with a magnetostrictive ring and an excitation source are disposed within the chamber to produce a highly agitated fluid discharge through the orifice. The magnetostrictive ring, chamber volume, and orifice cooperate to induce Helmholtz resonance frequencies in the fluid in the chamber to thereby enhance the agitation of the fluid discharge. A sheathing encapsulates the pulse member to protect it from contact with the fluid. A dampening element is also interposed between the pulse member and housing to isolate vibration.Type: GrantFiled: February 19, 2002Date of Patent: January 13, 2004Assignee: Halliburton Energy Services, Inc.Inventor: Peter Masak
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Patent number: 6629564Abstract: This invention comprises the use of a variable orifice valve as a flow controller and flow meter. Pressure measurements are taken upstream and downstream of the variable orifice valve by way of a differential pressure measurement mechanism. The differential pressure measurement mechanism may comprise two separate absolute pressure measurement devices or a single differential pressure measurement device. Flow rate through the valve is determined from the pressure drop across the valve. In wellbores having multiple zones, a variable orifice valve together with a differential pressure measurement mechanism may be deployed for each zone. The flow rate through each of the zones and at the surface can then be monitored and controlled.Type: GrantFiled: September 28, 2000Date of Patent: October 7, 2003Assignee: Schlumberger Technology CorporationInventors: Terizhandur S. Ramakrishnan, Gary M. Oddie, Sam Smonian
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Publication number: 20030173078Abstract: An oil shale formation may be treated using an in situ thermal process. Hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. Heat input into the formation may be controlled to maintain a temperature below about a maximum selected temperature.Type: ApplicationFiled: April 24, 2002Publication date: September 18, 2003Inventors: Scott Lee Wellington, Ilya Emil Berchenko, Eric Pierre de Rouffignac, Thomas David Fowler, John Michael Karanikas, Robert Charles Ryan, Gordon Thomas Shahin, George Leo Stegemeier, Harold J. Vinegar, Etuan Zhang
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Publication number: 20030173079Abstract: The invention relates to the oil industry and can be used for testing the intake capacity of a well and perform an action on a bottom zone thereof. Said invention makes it possible to increase the number of measured parameters and improve the accuracy of characterisation of the well, the well bottom zone and a formation. The inventive method consists in performing a pulse nonstationary injection of a reagent and measuring the injection pressure and the reagent flow on the measuring section of an injection line before the wellhead. A cumulative consumption of work supplied for nonstationary flow of the reagent consumption unit in the well bottom zone is defined. Skin-effect factor is calculated taking into consideration the current conductivity of the formation. The injection mode is modified when required filtration properties of the bottom well zone determined according to the skin-effect are obtained.Type: ApplicationFiled: January 7, 2003Publication date: September 18, 2003Inventor: Andrey Yegorovich Chikin
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Patent number: 6609568Abstract: An apparatus and method capable of incrementally decreasing the borehole pressure at a variable rate by controlling a test volume within the borehole. The system includes an incrementally controllable pump, closed loop feedback and a controller for drawing down the pressure of a test volume to a level just below formation pressure. This incremental drawdown system will significantly reduce the overall measurement time, thereby increasing drilling efficiency and safety.Type: GrantFiled: July 20, 2001Date of Patent: August 26, 2003Assignee: Baker Hughes IncorporatedInventors: Volker Krueger, Matthias Meister, John M. Michaels, Jaedong Lee, Stanley C. Jones
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Patent number: 6604581Abstract: Fluid property sensors and associated methods of calibrating sensors in a well provide enhanced well monitoring and control. In one described embodiment, an external venturi flowmeter is utilized to determine a flow rate of fluid from a zone into a tubing string, independent of flow into the tubing string of fluid produced from any upstream zone. In another described embodiment, a gamma ray fluid density sensor utilizes a unique combination of gamma ray sources and detectors to determine a density of fluid flowing through a tubing string. In yet another embodiment, external tubing string sensors are used to determine properties of fluid from a zone into a tubing string, independent of flow into the tubing string of fluid produced from any upstream zone. In still another embodiment, sensor systems for multiple independently produced zones are calibrated.Type: GrantFiled: October 22, 2001Date of Patent: August 12, 2003Assignee: Halliburton Energy Services, Inc.Inventors: Gordon L. Moake, Eugene Linyaev, Robert A. Moore, John P. Rogers
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Patent number: 6575244Abstract: A borehole includes a tubular member, a sealing member for sealing an annulus between the tubular member and the borehole, a pump for pumping fluidic materials into the tubular member, and an automatic choke for controllably releasing pressurized fluidic materials out of the annulus. A system and method monitor the operating pressure within the tubular member and compare the actual operating pressure with a desired operating pressure. The difference between the actual and desired operating pressure is then processed to control the operation of the automatic choke to thereby controllably bleed pressurized fluidic materials out of the annulus thereby creating back pressure within the borehole.Type: GrantFiled: July 31, 2001Date of Patent: June 10, 2003Assignee: M-I L.L.C.Inventors: Lingo Chang, Roger Suter, Alan Burkhard
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Patent number: 6571873Abstract: A method is disclosed for controlling pressure in a wellbore during drilling. The method includes operating a drilling system to have a first fluid pressure gradient inside a drillstring extending from the earth's surface to a drill bit at the bottom of the wellbore. The drilling system has a second fluid pressure gradient lower than the first fluid pressure gradient in an annular space between the drillstring and the wellbore from a selected depth in the wellbore to the earth's surface. Introduction of drilling fluid to the inside of the drillstring is stopped, and fluid flow in the annular space from a point below the selected depth to a point above the selected depth is selectively controlled to cause a substantially constant fluid pressure at a predetermined depth in the wellbore.Type: GrantFiled: February 20, 2002Date of Patent: June 3, 2003Assignee: ExxonMobil Upstream Research CompanyInventor: L. Donald Maus
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Publication number: 20030079875Abstract: A method for assessing the fracture pressure closure is proposed. This method includes first injecting a fluid into the formation at a first generally constant rate Q to create a fracture, and then, dropping the pumping rate to significantly smaller feed rate q so that the volume of the fracture becomes constant, in other words. As the fracture volume becomes constant at equilibrium, the well is shut-in. The wellbore pressure is monitored and the closure pressure is determined from the analysis of the wellbore pressure using a time-function of the dimensionless “shut-in” time, defined as the ratio of time since shutting to pumping time. This method provides a way of estimating the friction component of the monitored wellbore pressure due to the fracture tortuosity and friction.Type: ApplicationFiled: June 24, 2002Publication date: May 1, 2003Inventor: Xiaowei Weng
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Publication number: 20030066649Abstract: A subterranean well production system utilizes a single well to perform both hydrocarbon fluid production and water dumpflooding processes. The well has a primary wellbore that is communicated with first and second subterranean zones respectively containing hydrocarbon fluid and higher pressure water. A second, lateral wellbore extends from the primary wellbore and communicates with the first zone. A remotely controllable routing system, including a valved production tubing structure extending through the primary wellbore, is operable to (1) flow hydrocarbon fluid from the first zone to the surface via the production tubing and (2) simultaneously dumpflood water from the second zone into the first zone, via the production tubing, to increase the pressure within the first zone and thereby increase the hydrocarbon fluid production rate.Type: ApplicationFiled: August 13, 2002Publication date: April 10, 2003Inventors: Leo W. Koot, Michael R. Konopczynski
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Publication number: 20030042016Abstract: A petroleum well having a borehole extending into a formation is provided. A piping structure is positioned within the borehole, and an induction choke is positioned around the piping structure downhole. A communication system is provided along the piping structure between a surface of the well and the induction choke. A downhole module is positioned on an exterior surface of the piping structure and is configured to measure characteristics of the formation. The formation characteristics, such as pressure and resistivity, are communicated to the surface of the well along the piping structure.Type: ApplicationFiled: August 28, 2002Publication date: March 6, 2003Inventors: Harold J. Vinegar, Robert Rex Burnett, William Mountjoy Savage, Frederick Gordon Carl, Jr, Ilya Emil Berchenko
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Patent number: 6523609Abstract: A gauge carrier comprises a main body capable of incorporation into a suitable drill string, and a separate instrument housing including a gauge, the instrument housing being securable to the main body. The main body includes a handling region suitable for being handled by rig tongs, such that the instrument housing may be attached substantially along that handling region subsequently to its being handled. The handling region is located substantially centrally along the length of the main body. The main body includes at least one protective region having a larger cross section than the majority of the main body.Type: GrantFiled: September 6, 2000Date of Patent: February 25, 2003Assignee: Antech LimitedInventor: Antoni Miszewski
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Patent number: 6513596Abstract: A well data monitoring system which enables annulus pressure and other well parameters to be monitored in the outer annuli of the well casing program without adding any pressure containing penetrations to the well system. This non-intrusive approach to monitoring pressure and other well parameters in the annuli preserves the pressure integrity of the well and maximizes the safety of the well. In the preferred embodiment an intelligent sensor interrogation system which can be located externally or internally of the pressure containing housing of the wellhead is capable of interrogating and receiving data signals from intelligent well data sensors which are exposed to well parameters within the various annuli of the well and wellhead program.Type: GrantFiled: February 2, 2001Date of Patent: February 4, 2003Assignee: FMC Technologies, Inc.Inventor: Randy J. Wester
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Patent number: 6505681Abstract: Gaseous and liquid carbon dioxide (CO2) are applied to a landfill well to penetrate the landfill under rapid pressurization and depressurization repeated in cycles, with or without leachate or fluid in the well. These cycles can be repeated until the CO2 flows more freely down a lower pressure gradient in the well into the landfill surrounding the well screen, creating fissures in the landfill which allow methane and other gases to enter the well, thereby significantly enhancing methane and other landfill gas recovery.Type: GrantFiled: January 8, 2002Date of Patent: January 14, 2003Assignee: Subsurface Technologies IncorporatedInventors: Steven Catanla, Neil Mansuy
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Patent number: 6497280Abstract: A system of downhole communication and control is provided in methods and associated apparatus for data retrieval, monitoring and tool actuation. In a described embodiment, an item of equipment installed in a tubular string has a first communication device associated therewith. A tool conveyed into the tubular string has a second communication device therein. Communication is established between the first and second devices. Such communication may be utilized to control operation of the tool, retrieve status information regarding the item of equipment, supply power to the first device and/or identify the item of equipment to the tool.Type: GrantFiled: December 20, 2000Date of Patent: December 24, 2002Assignee: Halliburton Energy Services, Inc.Inventors: Harold Kent Beck, Clark E. Robison, Arthur Isadore Burke, Ian Colin Phillips, Elbert Juan Smith, Tance Jackson
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Patent number: 6491616Abstract: A method for the disposal of biosolids, the method comprising a) providing a supply of biosolids; creating a slurry of the biosolids suitable for injecting; selecting an injection formation below a ground surface, the injection formation comprising a natural gas formation in a gas accumulation zone; injecting the biosolids slurry into the injection formation at a pressure sufficient to create and maintain fractures within the selected injection formation; and allowing degradation of the injected biosolids slurry.Type: GrantFiled: April 15, 2002Date of Patent: December 10, 2002Assignees: Terralog Technologies USA, Inc., Terralog Technologies Inc.Inventors: Michael S. Bruno, Maurice B. Dusseault, Roman Bilak
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Patent number: 6481505Abstract: A system of downhole communication and control is provided in methods and associated apparatus for data retrieval, monitoring and tool actuation. In a described embodiment, an item of equipment installed in a tubular string has a first communication device associated therewith. A tool conveyed into the tubular string has a second communication device therein. Communication is established between the first and second devices. Such communication may be utilized to control operation of the tool, retrieve status information regarding the item of equipment, supply power to the first device and/or identify the item of equipment to the tool.Type: GrantFiled: December 20, 2000Date of Patent: November 19, 2002Assignee: Halliburton Energy Services, Inc.Inventors: Harold Kent Beck, Clark E. Robison, Arthur Isadore Burke, Ian Colin Phillips, Elbert Juan Smith, Tance Jackson
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Patent number: 6464021Abstract: A method for determining a desirable depth for drilling a horizontal well within an oil reservoir includes the steps of deploying a plurality of data sensors at discrete depths in a subsurface formation penetrated by a wellbore, gathering formation pressure data for the discrete depths using the data sensors, and determining the depth of a reservoir using the gathered formation pressure data. The depth within the reservoir may be determined by identifying from the gathered formation pressure data at least one depth whose corresponding formation pressure is suggestive of a reservoir. Once such a depth is identified, the wellbore itself or a lateral drainhole depending from the wellbore may be steered into the reservoir by maintaining the trajectory of the wellbore or drainhole at a substantially constant distance from a fluid contact within the reservoir.Type: GrantFiled: December 30, 1999Date of Patent: October 15, 2002Assignee: Schlumberger Technology CorporationInventor: John E. Edwards
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Publication number: 20020121371Abstract: Fluid property sensors and associated methods of calibrating sensors in a well provide enhanced well monitoring and control. In one described embodiment, an external venturi flowmeter is utilized to determine a flow rate of fluid from a zone into a tubing string, independent of flow into the tubing string of fluid produced from any upstream zone. In another described embodiment, a gamma ray fluid density sensor utilizes a unique combination of gamma ray sources and detectors to determine a density of fluid flowing through a tubing string. In yet another embodiment, external tubing string sensors are used to determine properties of fluid from a zone into a tubing string, independent of flow into the tubing string of fluid produced from any upstream zone. In still another embodiment, sensor systems for multiple independently produced zones are calibrated.Type: ApplicationFiled: October 22, 2001Publication date: September 5, 2002Inventors: Gordon L. Moake, Eugene Linyaev, Robert A. Moore, John P. Rogers
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Publication number: 20020121372Abstract: One or more subterranean zones are isolated from one or more other subterranean zones using a combination of solid tubulars and perforated tubulars.Type: ApplicationFiled: December 10, 2001Publication date: September 5, 2002Applicant: Shell Oil Co.Inventors: Robert Lance Cook, Lev Ring, Kevin Waddell, David Paul Brisco
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Publication number: 20020112854Abstract: An apparatus and method capable of incrementally decreasing the borehole pressure at a variable rate by controlling a test volume within the borehole. The system includes an incrementally controllable pump, closed loop feedback and a controller for drawing down the pressure of a test volume to a level just below formation pressure. This incremental drawdown system will significantly reduce the overall measurement time, thereby increasing drilling efficiency and safety.Type: ApplicationFiled: July 20, 2001Publication date: August 22, 2002Applicant: Baker Hughes IncorporatedInventors: Volker Krueger, Matthias Meister, John M. Michaels, Jaedong Lee, Stanley C. Jones
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Patent number: 6427785Abstract: Subsurface wellbore conditions are measured directly in the wellbore while the fluid circulation system is not pumping. The measured values are recorded at the subsurface location and subsequently transmitted to the well surface when circulation is resumed using fluid pulse telemetry (FPT). Real-time measurements made when the fluids are circulating are transmitted real time using FPT. Axially spaced measurements are used to obtain differential values. The apparatus of the invention comprises an assembly carried by a drill string that is used to selectively isolate the area within the well that is to be evaluated. The apparatus includes an assembly having axially spaced inflatable well packers that are used to isolate an uncased section of the wellbore. The apparatus is equipped with self-contained measuring and recording equipment, a fluid receiving reservoir, circulation valving, measurement while drilling equipment, and automated controls.Type: GrantFiled: September 21, 2001Date of Patent: August 6, 2002Inventor: Christopher D. Ward
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Patent number: 6429784Abstract: A casing sensor and methods for sensing using a casing sensor are disclosed. The casing sensor includes a casing shoe and a sensor coupled to the casing shoe. A casing data relay includes a downhole receiver coupled to a well casing and a transmitter coupled to the receiver. The casing sensor may be coupled to the transmitter. A drill string actuator may be controllable through the downhole receiver.Type: GrantFiled: February 19, 1999Date of Patent: August 6, 2002Assignee: Dresser Industries, Inc.Inventors: Jean Michel Beique, Morris Benjamin Robbins
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Publication number: 20020096324Abstract: An overall petroleum reservoir production optimization methodology permits the identification and remediation of unstimulated, under-stimulated, or simply poorly performing reservoir completed intervals in a multilayer commingled reservoir that can be recompleted using any of various recompletion methods (including but not limited to hydraulic fracturing, acidization, re-perforation, or drilling of one or more lateral drain holes) to improve the productivity of the well. This provides an excellent reservoir management tool and includes the overall analysis and remediation methodology that has been developed for commingled reservoirs. The specialized recompletion techniques can be used to improve the productivity of previously completed individual reservoir intervals in a commingled reservoir.Type: ApplicationFiled: September 28, 2001Publication date: July 25, 2002Applicant: Assignment BranchInventor: Bobby D. Poe
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Publication number: 20020092655Abstract: The present invention provides drilling systems for drilling subsea wellbores. The drilling system includes a tubing that passes through a sea bottom wellhead and carries a drill bit. A drilling fluid system continuously supplies drilling fluid into the tubing, which discharges at the drill bit bottom and returns to the wellhead through an annulus between the tubing and the wellbore carrying the drill cuttings. A fluid return line extending from the wellhead equipment to the drilling vessel transports the returning fluid to the surface. In a riserless arrangement, the return fluid line is separate and spaced apart from the tubing. In a system using a riser, the return fluid line may be the riser or a separate line carried by the riser. The tubing may be coiled tubing with a drilling motor in the bottom hole assembly driving the drill bit.Type: ApplicationFiled: March 8, 2002Publication date: July 18, 2002Applicant: Deep Vision LLCInventors: Roger W. Fincher, Roland May, Peter Fontana, Larry Watkins, James W. MacFarlane
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Patent number: 6389890Abstract: A hydraulic strain sensor for use with a downhole tool includes a housing having two chambers with a pressure differential between the two chambers. A mandrel is disposed in the housing. The mandrel is adapted to be coupled to the tool such that the weight of the tool is supported by the pressure differential between the two chambers. A pressure-responsive sensor in communication with the one of the chambers is provided to sense pressure changes in the chamber as the tool is accelerated or decelerated and to generate signals representative of the pressure changes.Type: GrantFiled: September 12, 2000Date of Patent: May 21, 2002Assignee: Schlumberger Technology CorporationInventors: Matthew Sweetland, Merlin D. Hansen
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Publication number: 20020056550Abstract: Gaseous and liquid carbon dioxide (CO2) are applied to a landfill well to penetrate the landfill under rapid pressurization and depressurization repeated in cycles, with or without leachate or fluid in the well. These cycles can be repeated until the CO2 flows more freely down a lower pressure gradient in the well into the landfill surrounding the well screen, creating fissures in the landfill which allow methane and other gases to enter the well, thereby significantly enhancing methane and other landfill gas recovery.Type: ApplicationFiled: January 8, 2002Publication date: May 16, 2002Inventors: Steven Catanla, Neil Mansuy
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Publication number: 20020043370Abstract: A method of and process for fractured well diagnostics for production data analysis for providing production optimization of reservoir completions via available production analysis and production logging data provides a quantitative analysis procedure for reservoir and fracture properties using commingled reservoir production data, production logs and radial flow and fractured interval analyses. This permits the in situ determination of reservoir and fracture properties for permitting proper and optimum stimulation treatment placement and design of the reservoir. The method is a rigorous analysis procedure for multilayer commingled reservoir production performance. Production logging data is used to correctly allocate production to each completed interval and defined reservoir zone. This improves the simulation and completion design and identifies zones to improve stimulation. The method supports computing the individual zone production histories of a commingled multi-layered reservoir.Type: ApplicationFiled: September 12, 2001Publication date: April 18, 2002Inventor: Bobby Poe
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Publication number: 20020043369Abstract: A petroleum well has an electronic module and a number of sensors which communicate with the surface using the tubing string and casing as conductors. Induction chokes at the surface and downhole electrically impede AC flow through the (tubing or casing if so configured) with the resulting voltage potential useful for power and communication. A high bandwidth, adaptable spread spectrum communications system is used to communicate between the downhole electronics module and a surface master spread spectrum modem. Downhole sensors, such as pressure, temperature, acoustic and seismic sensors accurately assess downhole physical conditions. In a preferred form, the electronics module and sensors are wireline insertable and retrievable into a side pocket mandrel in the tubing string.Type: ApplicationFiled: January 24, 2001Publication date: April 18, 2002Inventors: Harold J. Vinegar, Robert Rex Burnett, William Mountjoy Savage, Frederick Gordon Carl
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Patent number: 6367545Abstract: An electric wireline setting tool includes a controller and a plurality of sensors sensing pressure, temperature, flow rate, current, etc. The controller communicates with the surface and or makes decisions downhole with regard to a motor and pump to tailor their activity to ensure that the tool being set is setting optimally.Type: GrantFiled: March 3, 2000Date of Patent: April 9, 2002Assignee: Baker Hughes IncorporatedInventors: Richard Van Buskirk, Rustom K. Mody, Darrin L. Willauer
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Publication number: 20020011333Abstract: Subsurface wellbore conditions are measured directly in the wellbore while the fluid circulation system is not pumping. The measured values are recorded at the subsurface location and subsequently transmitted to the well surface when circulation is resumed using fluid pulse telemetry (FPT). Real-time measurements made when the fluids are circulating are transmitted real time using FPT. Axially spaced measurements are used to obtain differential values. The apparatus of the invention comprises an assembly carried by a drill string that is used to selectively isolate the area within the well that is to be evaluated. The apparatus includes an assembly having axially spaced inflatable well packers that are used to isolate an uncased section of the wellbore. The apparatus is equipped with self-contained measuring and recording equipment, a fluid receiving reservoir, circulation valving, measurement while drilling equipment, and automated controls.Type: ApplicationFiled: September 21, 2001Publication date: January 31, 2002Inventor: Christopher D. Ward
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Publication number: 20010050170Abstract: The present invention provides systems and methods for performing production testing in open holes and in cased holes that avoid transporting formation fluid to the surface. The invention essentially comprises a test string for testing a production zone intersecting a wellbore. The string further comprises a fluid communication member allowing flow of fluid therethrough, a sealing device for isolating a production zone intersecting said wellbore to allow fluid flow from said production zone into said fluid communication member, a second sealing device spaced apart from said first sealing device for isolating a second injection zone intersecting said wellbore, a pump for pumping fluid between zones, and flow control devices.Type: ApplicationFiled: January 5, 2001Publication date: December 13, 2001Inventors: Rune Woie, Harald Grimmer
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Publication number: 20010027865Abstract: A well data monitoring system which enables annulus pressure and other well parameters to be monitored in the outer annuli of the well casing program without adding any pressure containing penetrations to the well system. This non-intrusive approach to monitoring pressure and other well parameters in the annuli preserves the pressure integrity of the well and maximizes the safety of the well. In the preferred embodiment an intelligent sensor interrogation system which can be located externally or internally of the pressure containing housing of the wellhead is capable of interrogating and receiving data signals from intelligent well data sensors which are exposed to well parameters within the various annuli of the well and wellhead program.Type: ApplicationFiled: February 2, 2001Publication date: October 11, 2001Inventor: Randy J. Wester
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Patent number: 6296056Abstract: Subsurface wellbore conditions are measured directly in the wellbore while the fluid circulation system is not pumping. The measured values are recorded at the subsurface location and subsequently transmitted to the well surface when circulation is resumed using fluid pulse telemetry (FPT). Real-time measurements made/when the fluids are circulating are transmitted real time using FPT. Axially spaced measurements are used to obtain differential values. The apparatus of the invention comprises an assembly carried by a drill string that is used to selectively isolate the area within the well that is to be evaluated. The apparatus includes an assembly having axially spaced inflatable well packers that are used to isolate an uncased section of the wellbore. The apparatus is equipped with self-contained measuring and recording equipment, a fluid receiving reservoir, circulation valving, measurement while drilling equipment, and automated controls.Type: GrantFiled: July 19, 2000Date of Patent: October 2, 2001Assignee: Dresser Industries, Inc.Inventor: Christopher D. Ward
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Publication number: 20010015277Abstract: A packer for use inside a casing of a subterranean well includes a resilient element, a housing and a rupture disc. The resilient element is adapted to seal off an annulus of the well when compressed, and the housing is adapted to compress the resilient element in response to a pressure exerted by fluid of the annulus of a piston head of the housing. The housing includes a port for establishing fluid communication with the annulus. The rupture disc is adapted to prevent the fluid in the annulus from entering the port and contacting the piston head until the pressure exerted by the fluid exceeds a predefined threshold and ruptures the rupture disc.Type: ApplicationFiled: December 21, 2000Publication date: August 23, 2001Inventors: Vladimir Vaynshteyn, James D. Hendrickson, Jim B. Benton, Raghu Madhavan, Mitchell G. Willcox, Dinesh R. Patel
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Patent number: 6189612Abstract: Subsurface wellbore conditions are measured directly in the wellbore while the fluid circulation system is not pumping. The measured values are recorded at the subsurface location and subsequently transmitted to the well surface when circulation is resumed using fluid pulse telemetry (FPT). Real-time measurements made when the fluids are circulating are transmitted real time using FPT. Axially spaced measurements are used to obtain differential values. The apparatus of the invention comprises an assembly carried by a drill string that is used to selectively isolate the area within the well that is to be evaluated. The apparatus includes an assembly having axially spaced inflatable well packers that are used to isolate an uncased section of the wellbore. The apparatus is equipped with self-contained measuring and recording equipment, a fluid receiving reservoir, circulation valving, measurement while drilling equipment, and automated controls.Type: GrantFiled: February 1, 2000Date of Patent: February 20, 2001Assignee: Dresser Industries, Inc.Inventor: Christopher D. Ward
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Patent number: 6178815Abstract: The present invention provides a method for improving the quality of a formation fluid sample by taking the sample at a time when the formation fluid composition contains the most favorable portion of hydrocarbons. This task is accomplished by determining in real-time, the composition of the fluid flowing into a downhole tool from the formation. This method determines the optical density of the fluid as the fluid flows through the tool. An optical spectrum is generated from the density measurement. The optical spectrum is compared to a composite spectrum generated from a database of known fluid samples. As a result of the comparisons, there is a determination of the derivations between corresponding features of the two spectra. Adjustments are made to the components of the composite spectrum until the deviations between the two spectra are at an acceptable minimum. Determinations of the fluid composition are made from the composition of the composite spectrum at the minimum deviation.Type: GrantFiled: July 30, 1998Date of Patent: January 30, 2001Assignee: Schlumberger Technology CorporationInventors: Michelle Mary Felling, Charles W. Morris, Robert J. Butsch