序号 专利名 申请号 申请日 公开(公告)号 公开(公告)日 发明人
101 METHODS TO ESTIMATE DOWNHOLE DRILLING VIBRATION INDICES FROM SURFACE MEASUREMENT EP10807240.6 2010-08-06 EP2462475A1 2012-06-13 ERTAS, Mehmet, Deniz; BAILEY, Jeffrey, R.; BURCH, Damian, N.; WANG, Lei; PASTUSEK, Paul, E.; SUNDARARAMAN, Shankar
Method to estimate severity of downhole vibration for a wellbore drill tool assembly, comprising: identifying a dataset comprising selected drill tool assembly parameters; selecting a reference level of downhole vibration index for the drill tool assembly; identifying a surface drilling parameter and calculating a reference surface vibration attribute for the selected reference level of downhole vibration index; determining a surface parameter vibration attribute derived from at least one surface measurement or observation obtained in a drilling operation, the determined surface parameter vibration attribute corresponding to the identified surface drilling parameter; and estimating a downhole vibration index severity indicator by evaluating the determined surface parameter vibration attribute with respect to the identified reference surface vibration attribute.
102 METHOD FOR PREDICTING RATE OF PENETRATION USING BIT-SPECIFIC COEFFICIENTS OF SLIDING FRICTION AND MECHANICAL EFFICIENCY AS A FUNCTION OF CONFINED COMPRESSIVE STRENGTH EP05853623 2005-12-09 EP1836509A4 2010-08-04 CALHOUN WILLIAM MALCOLM; CAICEDO HECTOR ULPIANO; EWY RUSSELL THOMAS
103 METHOD OF DRILLING AND PRODUCING HYDROCARBONS FROM SUBSURFACE FORMATIONS EP06816516.6 2006-10-05 EP1954915A1 2008-08-13 DUPRIEST, Fred
A method associated with the production of hydrocarbons. In one embodiment, method for drilling a well is described. The method includes identifying a field having hydrocarbons. Then, one or more wells are drilled to a subsurface location in the field to provide fluid flow paths for hydrocarbons to a production facility. The drilling is performed by (i) estimating a drill rate for one of the wells; (ii) determining a difference between the estimated drill rate and an actual drill rate; (iii) obtaining mechanical specific energy (MSE) data and other measured data during the drilling of the one of the wells; (iv) using the obtained MSE data and other measured data to determine one of a plurality of limiters that limit the drill rate; (v) adjusting drilling operations to mitigate one of the plurality of limiters; and (vi) iteratively repeating steps (i)-(v) until the subsurface formation has been reached by drilling operations.
104 A METHOD FOR FACILITATING A WELLBORE OPERATION EP06700784.9 2006-01-17 EP1841948A1 2007-10-10 KOEDERITZ, William, L.; TARVIN, Terry, Lynn
A method for facilitating a wellbore operation with a wellbore apparatus (10) , the method comprising the steps of acquiring data with sensor apparatus at at least two points along said wellbore apparatus, the method further comprising the step of using the acquired data to calculate a mechanical specific energy value for each of said at least two points along said wellbore apparatus and monitoring said mechanical specific energy values.
105 METHOD FOR PREDICTING RATE OF PENETRATION USING BIT-SPECIFIC COEFFICIENTS OF SLIDING FRICTION AND MECHANICAL EFFICIENCY AS A FUNCTION OF CONFINED COMPRESSIVE STRENGTH EP05853623.6 2005-12-09 EP1836509A2 2007-09-26 CALHOUN, William, Malcolm; CAICEDO, Hector, Ulpiano; EWY, Russell, Thomas
A method for predicting the rate of penetration (ROP) of a drill bit drilling a well bore through intervals of rock of a subterranean formation is provided. The method uses an equation based upon specific energy principles. A relationship is determined between a bit-specific coefficient of sliding friction µ and confined compressive strength CCS over a range of confined compressive strengths CCS. Similarly, another relationship for the drill bit is determined between mechanical efficiency EFFM and confined compressive strength CCS over a range of confined compressive strengths CCS. Confined compressive strength CCS is estimated for intervals of rock through which the drill bit is to be used to drill a well bore. The rate of penetration ROP is then calculated utilizing the estimates of confined compressive strength CCS of the intervals of rock to be drilled and those determined relationships between the bit-specific coefficient of sliding friction µ and the mechanical efficiency EFFM and the confined compressive strengths CCS, as well as using estimated drill bit speeds N (RPM) and weights on bit (WOB).
106 SYSTEM, METHOD AND APPARATUS FOR PETROPHYSICAL AND GEOPHYSICAL MEASUREMENTS AT THE DRILLING BIT EP04814882.9 2004-12-20 EP1709280A2 2006-10-11 SPROSS, Ronald, L.; RODNEY, Paul, F.
Measurement of petrophysical and geophysical data of formations in a wellbore using a long gauge bit having at least one sensor therewith. The at least one sensor may be installed in at least one flute of the long gauge bit and/or in the long gauge portion thereof. Data for creating images of the formations are obtained at or near the bottom of the borehole and proximate to the long gauge bit used for drilling the borehole. Orientation of the long gauge bit is also available on a real time basis. Magnetic and/or gravitational sensors may be used in determining bit orientation. The flutes of the long gauge bit and the long gauge portion thereof may have standard inserts to accommodate various types of different sensors and electronic packages therefor.
107 Méthode et système d'estimation en temps réel d'au moins un paramètre lié au comportement d'un outil de fond de puits EP97401298.1 1997-06-09 EP0816630A1 1998-01-07 Fabret, Isabelle; Mabile, Claude; Desplans, Jean-Pierre

La présente invention concerne un système et une méthode d'estimation du comportement effectif d'un outil de forage fixé à l'extrémité d'une garniture de forage et entraîné en rotation dans un puits par des moyens d'entraînement situés en surface, dans laquelle on utilise un modèle physique non linéaire du processus de forage fondé sur des équations générales de la mécanique. Dans la méthode, on effectue les étapes suivantes:

  • on identifie et on calcule les paramètres dudit modèle en prenant en compte les paramètres dudit puits et de ladite garniture,
  • on linéarise ledit modèle autour d'un point de fonctionnement,
  • on réduit ledit modèle linéarisé en ne conservant que certains des modes propres de la matrice d'état dudit modèle,
  • on calcule, en temps réel, le déplacement de l'outil de forage ou l'effort appliqué à l'outil, à l'aide du modèle réduit et d'au moins un paramètre mesuré en surface.

108 DISPOSITIF DE MESURE DU DEPLACEMENT D'UNE TETE D'INJECTION D'UN MAT DE FORAGE EP92907190.0 1992-02-27 EP0528010B1 1995-04-26 ETCHEGOYEN, Didier; HENNEUSE, Henry
A device for measuring the movement of a drill pipe string, the end of which is held during drilling by an attachment assembly (12) movably along at least one guide rail (16), comprises a sensor assembly (38) mounted on the attachment assembly with a roller (42) designed to run on the rail as the attachment assembly moves.
109 Depth measuring device with wear resistant guide means EP91402657.0 1991-10-04 EP0480808A3 1992-07-22 Cooper, Neal

A cable length measuring device, comprising guide rollers for maintaining the cable in a straight line along a given segment of a line, and two encoding wheels disposed tangentially to the straight segment cable; additional guides, the ends of which bearing against the cable is made of a wear resistant material, are provided between the guide rollers and the tangential wheel/cable contact area.

110 System and method for monitoring drill bit depth EP90202463.7 1990-09-18 EP0422706A3 1992-07-08 Casso, Christopher; Normore, Andrew Derek; Slagel, Peter Shieffield

Methods and apparatus for accurately determining drill bit depth are provided. A hook load is sampled at a rate of at least 4 Hz and is compared to a load threshold to establish a slips-in condition. A determination is made retroactively that the drill string stopped moving when the hook load passed through a high dynamic threshold. On the slips-out procedure, the identical high threshold is used, with movement established when the hook load exceeds the high threshold. The high dynamic threshold corresponds to the points at which the drill string actually stops and starts moving in the slips-in and slips-out procedures. The apparatus provided is a drawworks encoder mounting assembly which retrofits an auxiliary brake section of the drawworks or the rotary seal air coupler of a drawworks clutch. A split ring gear fits around and is secured to the rotating cylinder of the rotary seal air coupler. The split ring gear is part of a pulley having another gear and a drive belt, such that rotation of the drum and rotorseal air coupler cylinder is translated to a shaft of an encoder coupled to the second gear. The encoder thereby tracks the rotational movement of the drawworks drum. At desired times, also provided is a second encoder which is part of a calibrator which, via a calibrator wire, precisely measures the location of the travelling block relative to a known vertical location. The first and second encoder readings are compared continuously and are used to provide excellent calibrations between the drum rotation and the travelling block movement.

111 Core monitoring device EP86302156.4 1986-03-24 EP0197696B1 1991-09-25 Park, Arthur; Wilson, Bobby Talma
112 Procedure for measuring the rate of penetration of a drill bit EP88200619.0 1988-04-05 EP0289068B1 1991-03-27 Kerbart, Yves
113 METHODS TO ESTIMATE DOWNHOLE DRILLING VIBRATION AMPLITUDE FROM SURFACE MEASUREMENT EP10807239.8 2010-08-06 EP2462315B1 2018-11-14 ERTAS, Mehmet, Deniz; BAILEY, Jeffrey, R.; BURCH, Damian, N.; WANG, Lei; PASTUSEK, Paul, E.; SUNDARARAMAN, Shankar
Method to estimate severity of downhole vibration for a drill tool assembly, including: identifying a dataset comprising selected drill tool assembly parameters; selecting a reference level of downhole vibration amplitude for the drill tool assembly; identifying a surface drilling parameter and calculating a reference surface vibration attribute for the selected reference level of downhole vibration amplitude; determining a surface parameter vibration attribute derived from at least one surface measurement or observation obtained in a drilling operation, the determined surface parameter vibration attribute corresponding to the identified surface drilling parameter; and estimating a downhole vibration severity indicator by evaluating the determined surface parameter vibration attribute with respect to the identified reference surface vibration attribute.
114 DIRECTIONAL DRILLER QUALITY REPORTING SYSTEM AND METHOD EP14900677 2014-08-29 EP3186478A4 2018-04-18 MOORE JAMES WILSON; HOLTZ STEPHEN ROBERT
System and method for analyzing and evaluating the performance of a directional driller (“DD”) include acquiring and analyzing drilling data in real time, identifying activities and decisions that are the responsibility of the directional driller, and confirming whether or not the directional driller's decisions were appropriate or not and in what timeframe. The system and method may provide output information for evaluation purposes, for example, in the form of a directional drilling quality report. The directional drilling quality report may allow evaluation of an individual directional driller and also comparison of directional drillers relative to each other. The use of real-time drilling data allows the report to be modified to reflect actual drilling conditions and objectives as needed.
115 METHODS TO ESTIMATE DOWNHOLE DRILLING VIBRATION AMPLITUDE FROM SURFACE MEASUREMENT EP10807239 2010-08-06 EP2462315A4 2017-09-27 ERTAS MEHMET DENIZ; BAILEY JEFFREY R; BURCH DAMIAN N; WANG LEI; PASTUSEK PAUL E; SUNDARARAMAN SHANKAR
Method to estimate severity of downhole vibration for a drill tool assembly, including: identifying a dataset comprising selected drill tool assembly parameters; selecting a reference level of downhole vibration amplitude for the drill tool assembly; identifying a surface drilling parameter and calculating a reference surface vibration attribute for the selected reference level of downhole vibration amplitude; determining a surface parameter vibration attribute derived from at least one surface measurement or observation obtained in a drilling operation, the determined surface parameter vibration attribute corresponding to the identified surface drilling parameter; and estimating a downhole vibration severity indicator by evaluating the determined surface parameter vibration attribute with respect to the identified reference surface vibration attribute.
116 DIRECTIONAL DRILLER QUALITY REPORTING SYSTEM AND METHOD EP14900677.7 2014-08-29 EP3186478A1 2017-07-05 MOORE, James Wilson; HOLTZ, Stephen Robert
System and method for analyzing and evaluating the performance of a directional driller (“DD”) include acquiring and analyzing drilling data in real time, identifying activities and decisions that are the responsibility of the directional driller, and confirming whether or not the directional driller's decisions were appropriate or not and in what timeframe. The system and method may provide output information for evaluation purposes, for example, in the form of a directional drilling quality report. The directional drilling quality report may allow evaluation of an individual directional driller and also comparison of directional drillers relative to each other. The use of real-time drilling data allows the report to be modified to reflect actual drilling conditions and objectives as needed.
117 SYSTEM AND METHOD FOR DETERMINING TORSION USING AN OPTO-ANALYTICAL DEVICE EP12883815 2012-08-31 EP2877826A4 2016-03-16 PELLETIER MICHAEL T; FREESE ROBERT P; CHEN SHILIN
In one embodiments, a method includes drilling a wellbore in a formation with a drilling tool. The method further includes receiving electromagnetic radiation using an opto-analytical device coupled to the drilling tool. The method also includes determining torsion associated with drilling the wellbore based on the received electromagnetic radiation.
118 Automated rate of penetration optimization while milling EP15156816.9 2015-02-26 EP2924234A2 2015-09-30 Tunc, Gokturk; Johnson, Ashley Bernard; Sharma, Anurag; Fairweather, Alan; Aldred, Walter David

A method for automating a downhole milling process includes receiving an input stream from at least one sensor within a downhole milling system, and segmenting the input stream. A safe operating envelope is identified based on segments of the input stream and models for the segments. At least one parameter of the milling system is then automatically changed along a path of optimal rate of penetration while remaining within the safe operating envelope. In some embodiments, an input stream may include surface pressure and the safe operating envelope may include swarf transport conditions.

119 DRILLING SPEED AND DEPTH COMPUTATION FOR DOWNHOLE TOOLS EP13806290 2013-05-20 EP2864587A4 2015-09-09 SUGIURA JUNICHI
A method for managing a drilling operation, including generating, by a first sensor and a second sensor of a bottom hole assembly (BHA), a first time based data log and a second time based data log, respectively, representing a borehole parameter along a drilling trajectory, determining, by a computer processor of the BHA and during the drilling operation, a time shift by comparing the first time based data log and the second time based data log, where offsetting the first and second time based data logs by the time shift maximizes a correlation factor of the first and second time based data logs, and determining, within a pre-determined time period from generating the first and second time based data logs, a drilling speed based on the time shift and a pre-determined distance between the first sensor and the second sensor.
120 METHOD OF DRILLING AND PRODUCING HYDROCARBONS FROM SUBSURFACE FORMATIONS EP06816516 2006-10-05 EP1954915A4 2015-08-12 DUPRIEST FRED
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