Patent application number | Description | Published |
20100282512 | SYSTEM AND METHOD FOR DETERMINING MOVEMENT OF A DRILLING COMPONENT IN A WELLBORE - 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. | 11-11-2010 |
20100319991 | Wall Contact Caliper Instruments for Use in a Drill String - A drill string caliper includes a mandrel configured to be coupled within a drill string. At least one laterally extensible arm is coupled to an exterior of the mandrel. A biasing device is configured to urge the at least one arm into contact with a wall of a wellbore. A sensor is configured to generate an output signal corresponding to a lateral extent of the at least one arm. | 12-23-2010 |
20110077867 | METHOD AND APPARATUS FOR DETERMINING FORMATION AND FLUID PROPERTIES - A downhole tool and method for determining a parameter of a formation as a function of radial distance from the borehole into the formation. The tool comprising a nuclear source for irradiating the formation and a plurality of sensors each independently measuring a density of the formation at a different radial depth into the formation. A processor combines the density measurements for determining the parameter of the formation as a function of radial distance. | 03-31-2011 |
20130047696 | INTERVAL DENSITY PRESSURE MANAGEMENT METHODS - 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. | 02-28-2013 |
20130048380 | WELLBORE INTERVAL DENSITIES - 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. | 02-28-2013 |
20130049983 | METHOD FOR CALIBRATING A HYDRAULIC MODEL - A method for a hydraulic model for subterranean drilling fluids includes acquiring first and second axially spaced temperature and pressure measurements in the wellbore. The pressure measurements may 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(ies) may be processed in combination with the temperature and pressure measurements to compute one or more unknown coefficients of the hydraulic model. | 02-28-2013 |
20130054146 | METHODS FOR EVALUATING CUTTINGS DENSITY WHILE DRILLING - 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. | 02-28-2013 |
20130090854 | METHODS FOR EVALUATING BOREHOLE VOLUME CHANGES WHILE DRILLING - 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. | 04-11-2013 |
20130090855 | METHODS FOR EVALUATING INFLOW AND OUTFLOW IN A SUBTERRAEAN WELLBORE - 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. | 04-11-2013 |
20140286539 | INVERSION-BASED WORKFLOW FOR PROCESSING NUCLEAR DENSITY IMAGES IN HIGH-ANGLE AND HORIZONTAL WELLS - Methods and apparatus for characterizing a subterranean formation traversed by a wellbore including collecting data from the formation using a tool wherein the tool collects data to form an azimuthal image, characterizing a section of the formation comprising data and images acquired in a high angle wellbore section or horizontal wellbore section using a parametric model, and performing an inversion using apparent densities and volumetric photoelectric factor images to build a formation model wherein the inversion is tailored for high angle wellbore sections and/or horizontal wellbore sections. | 09-25-2014 |
20140353037 | Determining Correct Drill Pipe Length And Formation Depth Using Measurements From Repeater Subs Of A Wired Drill Pipe System - A method includes accepting as input to a processor measurements of a characteristic of a subsurface formation made at a plurality of spaced apart positions along a pipe string moved along a wellbore. Measurements are made of pipe string depth in the wellbore from the Earth's surface. The measurements of pipe string depth include measurements of apparent depth of each of the spaced apart locations. The subsurface formation is identified from the measurements of the characteristic. A true depth of the subsurface formation is made using the measurements of pipe string depth and apparent depth of the formation from each of the spaced apart positions. A record of measurements of the characteristic with respect to depth corrected for changes in length of the pipe string caused by axial forces along the pipe string is generated. | 12-04-2014 |
Patent application number | Description | Published |
20100307742 | METHOD OF DETERMINING AND UTILIZING HIGH FIDELITY WELLBORE TRAJECTORY - Various methods are disclosed, comprising obtaining a plurality of raw depth measurements for a wellbore; obtaining survey data about a bottom hole assembly; obtaining depth compensation information; calculating a plurality of compensated depth measurements from the raw depth measurements and the depth compensation information and one or more additional corrections for residual pipe compliance, tide, and rig heave; calculating sag angle and correcting the survey data with the sag angle; determining a high fidelity wellbore trajectory from the compensated depth measurements and the survey data; and then employing the high fidelity wellbore trajectory in various drilling, formation evaluation, and production and reservoir analysis applications. Depth compensation information may comprise at least one of weight on bit, a friction factor, temperature profile, borehole profile, drill string mechanical properties, hookload, and drilling fluid property. The surveys may include both static and continuous surveys. | 12-09-2010 |
20100312478 | LOG PROCESSING IN HIGHLY DEVIATED WELLBORES - A method for processing well logging data includes method dividing the well logging data into a number of constant dimensional effect segments, where each constant dimensional effect segment defines an interval having a similar dimensional effect on the log response. The well logging data is taken from a highly deviated well, which may include portions deviated at greater than 90-degrees. The method further includes dividing the constant dimensional effect segments into a number of constant property intervals, each constant dimensional effect segment including at least one corresponding constant property interval, and each constant property interval defining a wellbore distance over which a formation property is substantially constant that results in a log response having a low variance. The method further includes providing the constant property intervals to an output device. The method further includes determining constant property intervals in 3D volume space projected them into true stratigraphic thickness, and providing the resulting log-squared data to the output device. | 12-09-2010 |
20110184711 | METHOD FOR ESTIMATING FORMATION PERMEABILITY USING TIME LAPSE MEASUREMENTS - A method for determining permeability of a subsurface formation includes measuring a parameter related to fluid content of the formation at a first time from within a wellbore penetrating the formation. A rate of entry of fluid from the wellbore into the formation is determined from the measurement of the parameter made at the first time. The permeability is determined from the rate of entry. | 07-28-2011 |
20110290011 | IDENTIFICATION OF CASING COLLARS WHILE DRILLING AND POST DRILLING USING LWD AND WIRELINE MEASUREMENTS - Systems and methods identify and/or detect one or more features of a well casing by utilizing one or more downhole measurements obtainable by a downhole component. The one or more features of the well casing are identifiable and/or detectable from the one or more measurements associated with one or more properties of the one or more features of the well casing. The one or more measurements for indentifying and/or detecting a presence and/or a location of the one or more features of the well casing include sonic measurements, nuclear measurements, gamma ray measurements, photoelectric measurements, resistivity measurements and/or combinations thereof. | 12-01-2011 |
20120055711 | WALL CONTACT CALIPER INSTRUMENTS FOR USE IN A DRILL STRING - A drill string caliper includes a mandrel configured to be coupled within a drill string. At least one laterally extensible arm is coupled to an exterior of the mandrel. A biasing device is configured to urge the at least one arm into contact with a wall of a wellbore. A sensor is configured to generate an output signal corresponding to a lateral extent of the at least one arm. | 03-08-2012 |
20120188236 | System, Method and Apparatus for Visualizing Changes in Cylindrical Volumes - A method includes interpreting first dimensional data such as a caliper log for a wellbore at a first time, and interpreting second dimensional data such as a caliper log for the wellbore at a second time. The method further includes determining a dimensional differential in response to the first dimensional data and the second dimensional data. The dimensional differential includes a volume difference between cross-sectional profiles from the first dimensional data and the second dimensional data. The cross-sectional profiles for comparison may be at a specified axial location or range of axial locations in the wellbore. The method includes graphically displaying the dimensional differential by marking the dimensional differential with a first marker index where the first dimensional data is inside the second dimensional data, and with a second marker index where the first dimensional data is outside the second dimensional data. | 07-26-2012 |
20120201425 | Method and Apparatus for Visualizing Multi-Dimensional Well Logging Data with Shapelets - A method for visualizing parametric logging data includes interpreting logging data sets, each logging data set corresponding to a distinct value of a progression parameter, calculating a geometric image including a representation of data from each of the logging data sets corresponding to a wellbore measured depth, and displaying the geometric image(s) at a position along a well trajectory corresponding to the wellbore measured depth. The progression parameter includes time, a resistivity measurement depth, differing tool modes that are sampling different volumes of investigation, and/or sampling different physical properties. The geometric images include a number of parallel lines having lengths determined according to the logging data and/or an azimuthal projection of the logging data, a number of concentric axial projections, and/or shapelets determined from parallel lines and/or concentric axial projections. The method includes dynamically determining a selected measured depth, measured depth interval, and/or azimuthal projection angle. | 08-09-2012 |
20130085675 | Applications Based On Fluid Properties Measured Downhole - Downhole drilling fluid measurements are made as a function of time or as a function of depth. A change in the downhole drilling fluid measurements is correlated to a feature of a formation penetrated by a drill bit or to a feature of fluids in the formation. The downhole drilling fluid measurements may include density, photoelectric factor, hydrogen index, salinity, thermal neutron capture cross section (Sigma), resistivity, slowness, slowing down time, sound velocity, and elemental composition. The feature may include fluid balance, hole-cleaning, a kick, a shallow water flow, a formation fluid property, formation fluid typing, geosteering, geostopping, or an environmental correction. A downhole system has a measurement-while-drilling tool or a logging-while-drilling tool and a processor capable of obtaining the downhole drilling fluid measurements and correlating the change in the downhole drilling fluid measurements. | 04-04-2013 |
20130186688 | METHODS FOR DETERMINING FORMATION STRENGTH OF A WELLBORE - A system and a method may determine formation strength of a well. The system and the method may use pressure measurements and temperature measurements to determine controlled fracture pressures before the uncontrolled fracture pressure is reached. The system and the method may use pressure measurements and temperature measurements to determine closure stresses while drilling and may use the closure stresses with core and log measurements to optimize a hydraulic stimulation program. | 07-25-2013 |
Patent application number | Description | Published |
20090189654 | Common-Mode Feedback Method Using a Current Starved Replica Biasing - A method, system, and circuit design product for setting the common-mode voltage level of a charge pump to yield low duty cycle distortion from a voltage controlled oscillator (VCO). Differential charge pumps utilize common-mode feedback (CMF) networks to control the common-mode voltage level. A replica circuit of a current starved delay cell from a VCO replaces the unity gain buffering circuit within a common-mode feedback circuit. Inserting the current starved delay cell replica circuit permits adequate negative feedback compensation, while allowing a phase locked loop (PLL) to operate with a wide bandwidth. As a result of utilizing the replica circuit of a current starved delay cell from a VCO, the common-mode voltage level is optimally centered to interface with the VCO, thereby minimizing duty cycle distortion. | 07-30-2009 |
20090189701 | Single-Ended to Differential Translator to Control Current Starved Delay Cell Bias - A method, system, and circuit device for interfacing single-ended charge pump output to differential voltage controlled oscillator (VCO) inputs to yield low duty cycle distortion from a VCO. A single-ended charge pump output is utilized to create a compliment differential voltage leg, while optimally centering the common-mode voltage level to interface to a current starved ring VCO. A replica of the VCO's current starved delay cell is implemented along with negative feedback to generate the compliment differential voltage leg. The single-ended charge pump output is coupled to a first transistor, while a second transistor is coupled to the output of an error amplifier. The error amplifier utilizes negative feedback to bias the second transistor, forcing the output of the replica circuit to equal a reference voltage. | 07-30-2009 |
20090261890 | REGULATED VOLTAGE BOOST CHARGE PUMP FOR AN INTEGRATED CIRCUIT DEVICE - An apparatus and method for a regulated voltage boost charge pump for an integrated circuit (IC) device. The charge pump generally includes a plurality of switching networks and a lift capacitor that are intermittently coupled to an output capacitor or to a regulating transistor, a differential error amplifier biasing a gate terminal of the transistor, and a controller configured to alternate states of switches in the switching networks in a pre-selected timing relationship with a clock signal of the IC device. | 10-22-2009 |
20100026272 | METHOD AND APPARATUS FOR DISTRIBUTION OF A VOLTAGE REFERENCE IN INTEGRATED CIRCUITS - Inventive embodiments described here provide for accurately distributing a voltage reference to multiple cores of an integrated circuit (IC). A quasi-differential interface is used to transmit the voltage reference, and a virtual ground is established at a receiver located at each core location on the integrated circuit. In one embodiment, the receiver is an operational transconductance amplifier (OTA) that converts a virtual-ground-referenced voltage input to a current. In one embodiment, the OTA converts the virtual-ground-referenced voltage into three currents via three driving current sources operating relative to the virtual ground and the local ground of the core. Negative feedback controls the accuracy of this conversion and provides a way to cancel the effects of the distribution resistance. The current is sourced across the voltage domains between the virtual ground and the V | 02-04-2010 |
20110057727 | ADAPTIVE COMMON MODE BIAS FOR DIFFERENTIAL AMPLIFIER INPUT CIRCUITS - A method and apparatus for extending the common mode range of a differential amplifier. A circuit has a common mode detection circuit, a common mode voltage inversion circuit, and a differential amplifier. The common mode detection circuit receives a differential signal and detects a common mode voltage. The common mode voltage inversion circuit is coupled to the common mode detection circuit. The common mode voltage inversion circuit has an input node that receives the common mode voltage and an output node that outputs body voltage, wherein the common mode voltage inversion circuit creates an inverse relationship between the common mode voltage and the body voltage. The differential amplifier includes a differential pair of transistors that have a pair of body terminals coupled to the output node of the common mode voltage inversion circuit. | 03-10-2011 |
20120153909 | HYBRID FAST-SLOW PASSGATE CONTROL METHODS FOR VOLTAGE REGULATORS EMPLOYING HIGH SPEED COMPARATORS - Voltage regulator circuits and methods implementing hybrid fast-slow passgate control circuitry are provided to minimize the ripple amplitude of a regulated voltage output. In one aspect, a voltage regulator circuit includes a comparator, a first passgate device, a second passgate device, and a bandwidth limiting control circuit. The comparator compares a reference voltage to a regulated voltage at an output node of the voltage regulator circuit and generates a first control signal on a first gate control path based on a result of the comparing. The first and second passgate devices are connected to the output node of the regulator circuit. The first passgate device is controlled in a bang-bang mode of operation by the first control signal to supply current to the output node. The bandwidth limiting control circuit has an input connected to the first gate control path and an output connected to the second passgate device. The bandwidth limiting control circuit generates a second control signal based on the first control signal, wherein the second control signal is a slew rate limited version of the first control signal, and wherein the second passgate is controlled by the second control signal to supply current to the output node. | 06-21-2012 |
20120153910 | DUAL-LOOP VOLTAGE REGULATOR ARCHITECTURE WITH HIGH DC ACCURACY AND FAST RESPONSE TIME - Dual-loop voltage regulator circuits and methods in which a dual-loop voltage regulation framework is implemented with a first inner loop having a bang-bang voltage regulator to achieve nearly instantaneous response time, and a second outer loop, which is slower in operating speed than the first inner loop, to controllably adjust a trip point of the bang-bang voltage regulator to achieve high DC accuracy. | 06-21-2012 |
20120313597 | Wide-Bandwidth Linear Regulator - A linear regulator and a method of regulating a supply voltage are provided. Embodiments include a linear regulator with a first feedback loop and a second feedback loop. The first feedback loop is characterized by a first bandwidth and a first gain. The first feedback loop includes a first amplifier characterized by an output impedance which is significantly reduced in order to maximize the bandwidth of the first feedback loop when driving the capacitance of a control input of a series pass element. The second feedback loop is characterized by a second bandwidth and a second gain. The second feedback loop includes a second amplifier that controls the current in the first amplifier in the first feedback loop. | 12-13-2012 |
20140355661 | DECISION FEEDBACK EQUALIZER ('DFE') WITH A PLURALITY OF INDEPENDENTLY-CONTROLLED ISOLATED POWER DOMAINS - A Decision Feedback Equalizer (DFE) that includes: a plurality of input signal lines comprising at least one data signal line and a plurality of power control signal lines; at least one output signal line; and a plurality of independently-controlled isolated power domains, where each independently-controlled isolated power domain is coupled to a corresponding one of the power control signal lines, each of the power control signal lines configured to transmit a power control signal to the independently-controlled isolated power domain dynamically, and each independently-controlled isolated power domain selectively consumes power in response to the power control signal, each independently-controlled isolated power domain configured to be dynamically powered up or powered down without impacting signal processing operations. | 12-04-2014 |
20140376603 | TESTING A DECISION FEEDBACK EQUALIZER ('DFE') - Testing a Decision Feedback Equalizer (‘DFE’), the DFE including a summing amplifier operatively coupled to a plurality of latches and an input signal line for receiving a data signal, including: preventing a differential data signal from being received by the summing amplifier; and iteratively for each tap to be tested: setting a tap coefficient for each tap to zero; setting an output of the plurality of latches to a predetermined value; setting a tap coefficient for the tap to be tested to a full scale value; and determining whether a resultant output signal from the DFE matches a predetermined expected output signal. | 12-25-2014 |