| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 121 | Method and Apparatus for Removal of The Double Indication of Defects in Remote Eddy Current Inspection of Pipes | US14590921 | 2015-01-06 | US20150127274A1 | 2015-05-07 | Emmanuel Legendre; Thilo M. Brill; Richard A. Rosthal; Gerald N. Minerbo |
| The apparatus employs the remote field eddy-current (RFEC) inspection technique to electromagnetically measure physical parameters of a metallic pipe. RFEC devices inserted into and displaced along a cylindrical pipes may be used to measure the ratio of pipe thickness to electromagnetic skin-depth and thus allow for the non-invasive detection of flaws or metal loss. Typically these RFEC thickness measurements exhibit a so-called double-indication of flaws, an undesired artifact due to a double-peaked geometrical sensitivity function of the device.The method describes a means by which this double indication artifact may be removed by an appropriate processing of RFEC measurements performed by an apparatus specifically designed for this purpose. The invention is particularly well designed for applications in the oilfield industry. | ||||||
| 122 | System, method and computer program product to simulate the progressive failure of rupture disks in downhole environments | US13546613 | 2012-07-11 | US09009014B2 | 2015-04-14 | Robert Franklin Mitchell |
| Systems and related methods to simulate, predict, and report progressive failures of rupture disks in response to thermal expansion of trapped annular fluids. | ||||||
| 123 | Drilling System and Associated System and Method for Monitoring, Controlling, and Predicting Vibration in an Underground Drilling Operation | US14036486 | 2013-09-25 | US20150083493A1 | 2015-03-26 | Mark Ellsworth Wassell |
| A drilling system and associated systems and methods for monitoring, controlling, and predicting vibration of a drilling operation. The vibration information can include axial, lateral or torsional vibration of a drill string. | ||||||
| 124 | REMOTELY CONTROLLED APPARATUS FOR DOWNHOLE APPLICATIONS AND METHODS OF OPERATION | US14537542 | 2014-11-10 | US20150060143A1 | 2015-03-05 | Steven R. Radford; Khoi Q. Trinh; Jason R. Habernal; R. Keith Glasgow; John G. Evans; Bruce Stauffer; Johannes Witte |
| An apparatus for use downhole is disclosed that, in one configuration includes a downhole tool configured to operate in an active position and an inactive position and an actuation device, which may include a control unit. The apparatus includes a telemetry unit that sends a first pattern recognition signal to the control unit to move the tool into the active position and a second pattern recognition signal to move the tool into the inactive position. The apparatus may be used for drilling a subterranean formation and include a tubular body and one or more extendable features, each positionally coupled to a track of the tubular body, and a drilling fluid flow path extending through a bore of the tubular body for conducting drilling fluid therethrough. A push sleeve is disposed within the tubular body and coupled to the one or more features. A valve assembly is disposed within the tubular body and configured to control the flow of the drilling fluid into an annular chamber in communication with the push sleeve; the valve assembly comprising a mechanically operated valve and/or an electronically operated valve. Other embodiments, including methods of operation, are provided. | ||||||
| 125 | Modeling and Production of Tight Hydrocarbon Reservoirs | US14013207 | 2013-08-29 | US20150060054A1 | 2015-03-05 | Sanjeev Bordoloi; Namsu Park; Christopher David Ward |
| Methods for modeling a tight hydrocarbon reservoir intersected by a borehole. Methods include using an estimated hydrocarbons-in-place value for the tight hydrocarbon reservoir and a gas parameter associated with drilling the borehole to create a drilling model. The model may determine an operation of a well control device associated with the borehole; or correlate the hydrocarbons-in-place value with the gas parameter for the tight hydrocarbon reservoir. Other methods include determining, during the forming of the borehole, an operation of a well control device associated with the borehole using an estimated hydrocarbons-in-place for the tight hydrocarbon reservoir and a gas parameter. The gas parameter may comprise a detected gas parameter normalized using at least one corresponding drilling parameter. Further methods include employing the model for performing operations in another borehole drilled in the same reservoir. Further methods include using the model to estimate a second hydrocarbons-in-place value in the other borehole. | ||||||
| 126 | Method and apparatus for removal of the double indication of defects in remote eddy current inspection of pipes | US13266129 | 2010-06-25 | US08958989B2 | 2015-02-17 | Emmanuel Legendre; Thilo M. Brill; Richard A. Rosthal; Gerald N. Minerbo |
| The apparatus employs the remote field eddy-current (RFEC) inspection technique to electromagnetically measure physical parameters of a metallic pipe. RFEC devices inserted into and displaced along a cylindrical pipes may be used to measure the ratio of pipe thickness to electromagnetic skin-depth and thus allow for the non-invasive detection of flaws or metal loss. Typically these RFEC thickness measurements exhibit a so-called double-indication of flaws, an undesired artifact due to a double-peaked geometrical sensitivity function of the device. The method describes a means by which this double indication artifact may be removed by an appropriate processing of RFEC measurements performed by an apparatus specifically designed for this purpose. The invention is particularly well designed for applications in the oilfield industry. | ||||||
| 127 | Iterative drilling simulation process for enhanced economic decision making | US12179221 | 2008-07-24 | US08949098B2 | 2015-02-03 | William W. King |
| An iterative drilling simulation method and system for enhanced economic decision making includes obtaining characteristics of a rock column in a formation to be drilled, specifying characteristics of at least one drilling rig system; and iteratively simulating the drilling of a well bore in the formation. The method and system further produce an economic evaluation factor for each iteration of drilling simulation. Each iteration of drilling simulation is a function of the rock column and the characteristics of the at least one drilling rig system according to a prescribed drilling simulation model. | ||||||
| 128 | System and method for using controlled vibrations for borehole communications | US14145044 | 2013-12-31 | US08783342B2 | 2014-07-22 | Todd W. Benson |
| A system and method are provided for producing controlled vibrations within a borehole. In one example, the system includes a movement mechanism and a vibration control mechanism. The movement mechanism is configured to use mechanical energy provided by a mechanical energy source to enable translational movement of a first surface relative to a second surface to allow the first surface to repeatedly impact the second surface to produce a plurality of vibration beats, where the vibration beats will occur whenever the mechanical energy is provided by the mechanical energy source unless the provided mechanical energy is dampened to prevent the translational movement. The vibration control mechanism is configured to selectively control an amplitude of the vibration beats to encode information therein, where the amplitude of a vibration beat is selectively controlled by dampening the provided mechanical energy to regulate the impact of the first surface and the second surface. | ||||||
| 129 | System and method for drilling hammer communication, formation evaluation and drilling optimization | US14010259 | 2013-08-26 | US08678107B2 | 2014-03-25 | Todd W. Benson |
| A system and method are provided for producing controlled vibrations within a borehole. In one example, the system includes an encoder plate having a first surface, an anvil plate having a second surface, a movement mechanism configured to enable translational movement of the encoder plate relative to the anvil plate to allow the first surface to repeatedly impact the second surface to produce a plurality of vibration beats, and a vibration control mechanism configured to selectively control an amplitude of the vibration beats to encode information therein. | ||||||
| 130 | Methods and systems for designing and/or selecting drilling equipment using predictions of rotary drill bit walk | US13656527 | 2012-10-19 | US08606552B2 | 2013-12-10 | Shilin Chen |
| Methods and systems may be provided simulating forming a wide variety of directional wellbores including wellbores with variable tilt rates and/or relatively constant tilt rates. The methods and systems may also be used to simulate forming a wellbore in subterranean formations having a combination of soft, medium and hard formation materials, multiple layers of formation materials and relatively hard stringers disposed throughout one or more layers of formation material. Values of bit walk rate from such simulations may be used to design and/or select drilling equipment for use in forming a directional wellbore. | ||||||
| 131 | MULTIPLE DISTRIBUTED PRESSURE MEASUREMENTS | US13903377 | 2013-05-28 | US20130256033A1 | 2013-10-03 | Daniel D. Gleitman |
| Methods, computer programs, and systems for detecting at least one downhole condition are disclosed. Pressures are measured at a plurality of locations along the drillstring. The drillstring includes a drillpipe. At least one of the pressures is measured along the drillpipe. At least one downhole condition is detected based, at least in part, on at least one measured pressure. | ||||||
| 132 | Applications Based On Fluid Properties Measured Downhole | US13251769 | 2011-10-03 | US20130085675A1 | 2013-04-04 | Ankur Prakash; John C. Rasmus; Richard J. Radtke; Michael Evans; Lee Dolman |
| 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. | ||||||
| 133 | SYSTEM AND METHOD FOR STICK-SLIP CORRECTION | US13219125 | 2011-08-26 | US20130049982A1 | 2013-02-28 | Andreas Hartmann |
| A method of processing downhole measurement data includes: receiving formation measurement data generated by a downhole tool during a logging-while drilling operation over a selected time period; receiving a measured depth corresponding to the selected time period based on data taken at a surface location; receiving tool rotation data generated by measurements of a rotational rate of the downhole tool taken by a downhole sensor during the selected time period; calculating a new depth of the tool as a function of time over the selected time period based on a relationship between the tool rotation data and the measured depth; and correcting an original depth of the measurement data with the new depth. | ||||||
| 134 | METHODS AND SYSTEMS FOR DESIGNING AND/OR SELECTING DRILLING EQUIPMENT USING PREDICTIONS OF ROTARY DRILL BIT WALK | US13656527 | 2012-10-19 | US20130043077A1 | 2013-02-21 | Shilin Chen |
| Methods and systems may be provided simulating forming a wide variety of directional wellbores including wellbores with variable tilt rates and/or relatively constant tilt rates. The methods and systems may also be used to simulate forming a wellbore in subterranean formations having a combination of soft, medium and hard formation materials, multiple layers of formation materials and relatively hard stringers disposed throughout one or more layers of formation material. Values of bit walk rate from such simulations may be used to design and/or select drilling equipment for use in forming a directional wellbore. | ||||||
| 135 | Methods and systems for design and/or selection of drilling equipment based on wellbore drilling simulations | US12938151 | 2010-11-02 | US08352221B2 | 2013-01-08 | Shilin Chen |
| Methods and systems may be provided for simulating forming a wide variety of directional wellbores including wellbores with variable tilt rates and/or relatively constant tilt rates. The methods and systems may also be used to simulate forming a wellbore in subterranean formations having a combination of soft, medium and hard formation materials, multiple layers of formation materials and relatively hard stringers disposed throughout one or more layers of formation material. | ||||||
| 136 | DETERMINING A PROPERTY OF A FORMATION MATERIAL | US13517285 | 2010-12-22 | US20120255781A1 | 2012-10-11 | Jan-Jette Blangé |
| Method for determining a property of a formation material in the course of a jet drilling operation, wherein a fluid jet is blasted with erosive power into impingement with the formation material, the method comprising postulating a relationship between the erosive power and a removal rate of formation material as a result of the impingement of the fluid jet with the erosive power on said formation material, the relationship comprising a parameter related to at least one property of the formation material; determining removal rates of formation material for at least two settings of erosive power; and determining the at least one property of the formation material from the relationship and the determined removal rates in dependence on erosive power. | ||||||
| 137 | METHOD OF DETERMINING RESERVOIR PRESSURE | US13327182 | 2011-12-15 | US20120158310A1 | 2012-06-21 | John R. Adams; Siyavash Motealleh; Herbert M. Sebastian; Yuanlin Jiang; Bryan Dotson |
| A new approach is disclosed for measuring the pressure of tight gas reservoirs, using information obtain from continuous injection prior to hydraulic fracture stimulation. The technique can be obtained utilizing either bottom-hole or surface pressure gauges and properly instrumented surface injection pumps. The analysis is completed by plotting injection and rate data in a specialized form from terms arranged in Darcy's radial flow equation to obtain a curve or trend. The key component to proper application of this technique is to obtain both baseline and one or more calibration data sets. These calibration data sets are obtained by either increasing or decreasing the injection pressure and/or rate from the baseline data. Initial reservoir pressure is assumed, but the calibration data indicates if the guess was too high or low. Accurate estimates of reservoir pressure may be obtained in a few iterations. | ||||||
| 138 | Method and Apparatus for Removal of The Double Indication of Defects in Remote Eddy Current Inspection of Pipes | US13266129 | 2010-06-25 | US20120095686A1 | 2012-04-19 | Emmanuel Legendre; Thilo M. Brill; Richard A. Rosthal; Gerald N. Minerbo |
| The apparatus employs the remote field eddy-current (RFEC) inspection technique to electromagnetically measure physical parameters of a metallic pipe. RFEC devices inserted into and displaced along a cylindrical pipes may be used to measure the ratio of pipe thickness to electromagnetic skin-depth and thus allow for the non-invasive detection of flaws or metal loss. Typically these RFEC thickness measurements exhibit a so-called double-indication of flaws, an undesired artifact due to a double-peaked geometrical sensitivity function of the device. The method describes a means by which this double indication artifact may be removed by an appropriate processing of RFEC measurements performed by an apparatus specifically designed for this purpose. The invention is particularly well designed for applications in the oilfield industry. | ||||||
| 139 | PHASE WELLBORE STEERING | US12633192 | 2009-12-08 | US20110132662A1 | 2011-06-09 | MARK KENNETH DENNIS |
| A method of steering a drilling operation of a well using acoustic measurements. The method includes obtaining, using a central processing unit (CPU), a clean-wet matrix line for the well, where the clean-wet matrix line includes a number of normal compressional values, obtaining, using the CPU, the acoustic measurements from at least one logging while drilling tool at a current depth of the drilling operation, where the acoustic measurements include a compressional to shear velocity ratio and a delta-T compressional measurement, and determining, using the CPU, a current phase of the drilling operation by comparing the acoustic measurements to the clean-wet matrix line. The method further includes, in response to determining that the current phase is not a target phase, generating an updated well trajectory for steering the drilling operation toward the target phase and adjusting the drilling operation using the updated well trajectory. | ||||||
| 140 | Strength (UCS) of Carbonates Using Compressional and Shear Acoustic Velocities | US12754154 | 2010-04-05 | US20100263931A1 | 2010-10-21 | Umesh Prasad; David A. Curry |
| Acoustic velocities measured downhole are used to predict a rock strength using results of a regression analysis that include grain size. The grain size can be obtained from drill cuttings or from NMR measurements. The determined rock strength is used in drilling operations. | ||||||
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