| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 141 | METHODS FOR DETERMINING MECHANICAL SPECIFIC ENERGY FOR WELLBORE OPERATIONS | US12416998 | 2009-04-02 | US20100252325A1 | 2010-10-07 | MICHAEL N. PORCHE |
| A method for determining mechanical specific energy for a wellbore operation (e.g., drilling), the method including: measuring power input to machines used in a wellbore and producing a value for input power; calculating mechanical specific power for the operation based on the value for the input power; a computer-readable media for performing a step or steps of the method; and a computing unit for reading and performing the step or steps. This abstract is provided to comply with the rules requiring an abstract which will allow a searcher or other reader to quickly ascertain the subject matter of the technical disclosure and is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims, 37 C.F.R. 1.72(b). | ||||||
| 142 | Multi-physics inversion processing to predict pore pressure ahead of the drill bit | US11695730 | 2007-04-03 | US07782709B2 | 2010-08-24 | Cengiz Esmersoy |
| Methods are disclosed to predict pore pressure ahead of the drill bit while drilling a borehole through subsurface regions. | ||||||
| 143 | METHOD FOR DETERMINING FORMATION INTEGRITY AND OPTIMUM DRILLING PARAMETERS DURING DRILLING | US12326925 | 2008-12-03 | US20100133007A1 | 2010-06-03 | Ossama Ramzi Sehsah |
| A method for determining formation integrity during drilling of a wellbore includes determining an annulus fluid pressure in a wellbore during drilling thereof. The annulus pressure is adjusted by a predetermined amount. Flow rate of drilling fluid into the wellbore is compared to drilling fluid flow rate out of the wellbore. At least one of a formation pore pressure and a formation fracture pressure is determined from the annulus pressure when the compared flow rates differ by a selected amount. The method alternatively to determining pore and/or fracture pressure includes determining a response of the wellbore to the adjusted fluid pressure and determining the optimum annulus fluid pressure from the wellbore response. | ||||||
| 144 | Use of the dynamic downhole measurements as lithology indicators | US11357332 | 2006-02-17 | US07650241B2 | 2010-01-19 | Pushkar Jogi; Joachim Oppelt; Gerald Heisig; Volker Krueger; John Macpherson |
| A drilling system provides indications of the lithology of the formation being drilled by dynamically measuring at least one parameter of interest that is affected by the lithology of the formation being drilled. Suitably positioned sensors make dynamic measurements of parameters such as downhole weight on bit, bit torque, bit revolutions, rate of penetration and bit axial acceleration. One or more processors use the sensor measurements in conjunction with predetermined lithological models to determine whether the measurements indicate a change in formation lithology. Suitable models can be on derived expressions such as rock drillability, drilling response, dynamic drilling response, normalized or dimensionless torque; and formation shear strength. The lithological indications provided by the processor can be used to adjust drilling parameters, steer the BHA, monitor BHA health, and provide depth locations for bed boundaries and formation interfaces. | ||||||
| 145 | HIGH SPEED DATA TRANSFER FOR MEASURING LITHOLOGY AND MONITORING DRILLING OPERATIONS | US12192582 | 2008-08-15 | US20090201170A1 | 2009-08-13 | Hanno Reckmann; Pushkar N. Jogi |
| A system for determining at least one of a lithology of a formation traversed by a borehole and an operational condition of a component of a drill string disposed in the borehole, the system including: a sensor for performing downhole measurements of a drilling parameter, the sensor being disposed at least one of at and in the drill string; a high speed wired pipe telemetry system for transmitting the downhole measurements in real time, a processor coupled to the telemetry system for receiving the measurements, the processor disposed external to the drill string; and a computer processing system coupled to the processor, the computer processing system comprising a model that receives the downhole measurements and surface measurements of a drilling parameter as input, the model providing as output at least one of the lithology of the formation and the operational condition of the component. | ||||||
| 146 | Method and system for predicting performance of a drilling system for a given formation | US11215673 | 2005-08-30 | US07357196B2 | 2008-04-15 | William A. Goldman; Oliver Matthews, III; William W. King; Gary E. Weaver; Gerald L. Pruitt |
| A method and apparatus for predicting the performance of a drilling system for the drilling of a well bore in a given formation includes generating a geology characteristic of the formation per unit depth according to a prescribed geology model, obtaining specifications of proposed drilling equipment for use in the drilling of the well bore, and predicting a drilling mechanics in response to the specifications as a function of the geology characteristic per unit depth according to a prescribed drilling mechanics model. Responsive to a predicted drilling mechanics, a controller controls a parameter in the drilling of the well bore. The geology characteristic includes at least rock strength. The specifications include at least a bit specification of a recommended drill bit. Lastly, the predicted drilling mechanics include at least one of bit wear, mechanical efficiency, power, and operating parameters. A display is provided for generating a display of the geology characteristic and predicted drilling mechanics per unit depth, including either a display monitor or a printer. | ||||||
| 147 | Methods and system for design and/or selection of drilling equipment based on wellbore drilling simulations | US11462929 | 2006-08-07 | US20070032958A1 | 2007-02-08 | 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. | ||||||
| 148 | Use of the dynamic downhole measurements as lithology indicators | US11357332 | 2006-02-17 | US20060212224A1 | 2006-09-21 | Pushkar Jogi; Joachim Oppelt; Gerald Heisig; Volker Krueger; John Macpherson |
| A drilling system provides indications of the lithology of the formation being drilled by dynamically measuring at least one parameter of interest that is affected by the lithology of the formation being drilled. Suitably positioned sensors make dynamic measurements of parameters such as downhole weight on bit, bit torque, bit revolutions, rate of penetration and bit axial acceleration. One or more processors use the sensor measurements in conjunction with predetermined lithological models to determine whether the measurements indicate a change in formation lithology. Suitable models can be on derived expressions such as rock drillability, drilling response, dynamic drilling response, normalized or dimensionless torque; and formation shear strength. The lithological indications provided by the processor can be used to adjust drilling parameters, steer the BHA, monitor BHA health, and provide depth locations for bed boundaries and formation interfaces. | ||||||
| 149 | Multiple distributed pressure measurements | US11051762 | 2005-02-04 | US20050194184A1 | 2005-09-08 | Daniel 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 drilipipe. At least one downhole condition is detected based, at least in part, on at least one measured pressure. | ||||||
| 150 | Method of assaying downhole occurrences and conditions | US10668788 | 2003-09-23 | US20040059554A1 | 2004-03-25 | William A. Goldman; Lee Morgan Smith |
| A method for determining bit wear in a drill bit of a drilling rig system is disclosed. The method provides a first drill bit design. The first drill bit design having a first geometry. The method also generates a geological model of given formation. The geological model including a geological characteristic based on a length of formation drilled in a given amount of time. The method predicts the first wear rate of the first drill bit design based on the first geometry compared to the geological model for the length of formation drilled. | ||||||
| 151 | Method of assaying downhole occurrences and conditions | US10133078 | 2002-04-26 | US20030187582A1 | 2003-10-02 | William A. Goldman; Lee Morgan Smith |
| A method of assaying work of an earth boring bit of a given size and design comprises the steps of drilling a hole with the bit from an initial point to a terminal point. A plurality of electrical incremental actual force signals are generated, each corresponding to a force of the bit over a respective increment of the distance between the initial and terminal points. A plurality of electrical incremental distance signals are also generated, each corresponding to the length of the increment for a respective one of the incremental actual force signals. The incremental actual force signals and the incremental distance signals are processed to produce a value corresponding to the total work done by the bit in drilling from the initial point to the terminal point. Using such a basic work assay, a number of other downhole occurrences and/or conditions can be assayed. These include a wear rating for the type of bit, a determination of whether such a bit can drill a given interval of formation, and assessment of the abrasivity of rock drilled (which in turn can be used to modify the assays of other conditions and/or occurrences), a model of the wear of such a bit in current use, and a determination of the mechanical efficiency of the bit. | ||||||
| 152 | Realtime control of a drilling system using the output from combination of an earth model and a drilling process model | US10248704 | 2003-02-11 | US20030168257A1 | 2003-09-11 | Walter D. Aldred; Richard Meehan |
| A system is for controlling borehole operations using a computational drilling process model representing the combined effect of downhole conditions and the operation of a drillstring. The drilling process model is continually updated with downhole measurements made during a drilling operation. From the updated drilling process model, a set of optimum drilling parameters is determined and communicated to a surface equipment control system. Further, the system allows the surface equipment control system to automatically adjust current surface equipment control settings based on the updated optimum drilling parameters. Various control scripts are generated and executed to inform the surface equipment control system based on a present drilling mode. | ||||||
| 153 | Method and apparatus for determining potential abrasivity in a wellbore | US09511617 | 2000-02-23 | US06386297B1 | 2002-05-14 | Craig Hodges Cooley; David Alexander Curry; Leroy William Ledgerwood, III |
| A method is provided for generating an indicator of potential bit abrasion in a particular wellbore. Forensic wellbore data is obtained from at least one previously drilled wellbore which is determined to be comparable to the particular target wellbore. Typically, the comparable wellbore comprises an “offset” wellbore which is proximate the target wellbore, and which has similar geologic features. An inference engine computer program is provided which consists of executable program instructions. It is adapted to utilize a plurality of wellbore parameters, including the forensic wellbore data. The inference engine includes at least one rule matrix which defines a plurality of fuzzy sets. These fuzzy sets establish correspondence between the plurality of wellbore parameters and the indictor of potential bit abrasion. The inference engine computer program is loaded onto a data processing system. At least the forensic wellbore data is supplied as an input to the inference engine computer program. The data processing system is utilized to execute the program instructions of the inference engine computer program. This causes the application of the inputs to the inference engine computer program. The inference engine computer program produces as an output an indication of potential bit abrasion in the particular target wellbore. | ||||||
| 154 | Method of assaying downhole occurrences and conditions | US09598131 | 2000-06-21 | US06374926B1 | 2002-04-23 | William A. Goldman; Lee Morgan Smith |
| A method of assaying work of an earth boring bit of a given size and design comprises the steps of drilling a hole with the bit from an initial point to a terminal point. A plurality of electrical incremental actual force signals are generated, each corresponding to a force of the bit over a respective increment of the distance between the initial and terminal points. A plurality of electrical incremental distance signals are also generated, each corresponding to the length of the increment for a respective one of the incremental actual force signals. The incremental actual force signals and the incremental distance signals are processed to produce a value corresponding to the total work done by the bit in drilling from the initial point to the terminal point. Using such a basic work assay, a number of other downhole occurrences and/or conditions can be assayed. These include a wear rating for the type of bit, a determination of whether such a bit can drill a given interval of formation, and assessment of the abrasivity of rock drilled (which in turn can be used to modify the assays of other conditions and/or occurrences), a model of the wear of such a bit in current use, and a determination of the mechanical efficiency of the bit. | ||||||
| 155 | Method and apparatus for determining potential interfacial severity for a formation | US09511618 | 2000-02-23 | US06353799B1 | 2002-03-05 | Nigel Charles Meany; David Alexander Curry; Leroy William Ledgerwood, III; Craig Hodges Cooley |
| A method and apparatus are provided for generating an indicator of potential for abrupt changes in rock strength in a particular wellbore. Forensic wellbore data is obtained from at least one previously drilled wellbore which is determined to be comparable to the target wellbore. An interfacial severity computer program is provided. The program consists of executable program instructions. It is adapted to utilize a plurality of wellbore parameters, including at least one forensic wellbore data element. The interfacial severity computer program is loaded onto a data processing system. At least the forensic wellbore data, and possibly other wellbore parameter data elements, are supplied as an input to the interfacial severity computer program. The data processing system is utilized to execute program instructions of the interfacial severity computer program. This applies the inputs to the interfacial severity computer program which produces an output and indicator of the potential for abrupt changes in rock strength in the particular target wellbore. | ||||||
| 156 | Quantification of the characteristics of porous formations while drilling | US09461019 | 1999-12-15 | US06290000B1 | 2001-09-18 | Konstandinos S. Zamfes |
| A method is provided for establishing the quantity and quality of hydrocarbons in the pores of a formation while drilling. One sensor (TG), applied to gas liberated from drilling mud, outputs a signal proportional to the concentration of hydrocarbons. Additional information acquired while drilling is combined with the TG analysis for quantifying a fraction of hydrocarbon in the pores of the drilled formation. Further and better quantification of hydrocarbons is achieved by normalizing drilling characteristics which are independent of porosity such as mud weight, weight on bit, bit rotational speed, and sampling dilution compared to the overall circulation of mud. Further, quality of the hydrocarbons is determinable using a second gas sensor which outputs a decreasing signal with increased concentrations of heavy hydrocarbons in the liberated gas and outputs an increasing signal with increasing concentrations of light hydrocarbons. The ratio of the first TG signal to the difference of the first and second signals (DTG) is indicative of the quality of the hydrocarbon. | ||||||
| 157 | Method of controlling development of an oil or gas reservoir | US851919 | 1997-05-06 | US6002985A | 1999-12-14 | Stanley V. Stephenson |
| A method controlling development of an oil or gas reservoir uses a neural network and genetic algorithm program to define a neural network topology and the optimal inputs for that topology. The topology is defined from identified and selected (1) parameters associated with the formation or formations in which actual wells are drilled in the reservoir and (2) parameters associated with the drilling, completion and stimulation of those wells and (3) parameters associated with the oil or gas production from the wells. Subsequent drilling, completion and stimulation of the reservoir is determined and applied based on hypothetical alternatives input to the topology and resulting outputs. | ||||||
| 158 | Method of monitoring the drilling of a borehole | US547737 | 1990-07-02 | US5138875A | 1992-08-18 | Anthony Booer |
| The invention relates to a method of monitoring the drilling of a borehole through an earth formation with a rotating drill bit fixed at the lower end of a drillstring. At least one physical quantity associated with the vibrations resulting from the interaction of the rotating drill bit with the earth formation is detected and an oscillatory signal is generated in response thereto. Filter coefficients a.sub.k of an auto-regressive filter model are determined by fitting the filter output signal with the oscillatory signal. The reflection coefficients of the vibrations propagating along the drill string and being reflected by a mis-match of impedance of two successive elements of the system earth formation/drillstring are derived from the filter coefficients. Finally, the hardness of the formation being drilled, the contact of the drillstring with the borehole and the vibration level of the vibration along the drillstring are determined from the reflection coefficients. | ||||||
| 159 | Method of determining the porosity of an underground formation being drilled | US372987 | 1989-06-28 | US4981036A | 1991-01-01 | David Curry; Michael Sheppard |
| The invention relates to a method of determining the porosity of an undergound formation being drilled by a rotating drill bit mounted at the lower end of a drill string. The torque (TOR) and the weight (WOB) applied on the bit when drilling the underground formation are measured; the effect of the geometry of the drill bit on the torque and weight on bit response is determined; the porosity (phi) of the formation being drilled is derived from the measured TOR and WOB taking into account the effect of the geometry of the drill bit. Preferentially, the porosity phi is determined from the following equation:TOR=(k.sub.1 +k.sub.2.phi)WOB.sup.awhere k.sub.1, k.sub.2 and a are parameters characteristic of the geometry of the drill bit. | ||||||
| 160 | Formation volumetric evaluation while drilling | US316256 | 1989-02-27 | US4949575A | 1990-08-21 | John C. Rasmus |
| Formation Strength and other measurement while drilling parameters are combined to produce a formation volumetric analysis which may including the traditional volumetric components of clay volume, sand volume, total porosity, and water filled porosity. In shaley formations, the volumetric analysis may also include an excess or overpressure porosity. Formation Strength may be derived from measurements of torque and weight on bit and be corrected for such effects as bit dullness, mud weight and hydrostatic pressure balance. | ||||||
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