An apparatus can include a downhole tool having a fluid outlet connectable to a fluid inlet to define a flow path via a hollow interior of the tool, and a valve member capable of opening and constricting or closing the flow path. The apparatus further includes pipe within which a part of the tool is located, the tool being sealed with an interior of the pipe, preventing fluid flow in the pipe via the part of the tool. The pipe includes an openable valve for permitting flow of fluid from the pipe interior via another flow path interconnecting the pipe interior and outside. The valve is normally closed. When the valve member constricts or closes the first flow path, fluid pressure in the pipe increases to cause opening of the valve and venting of pressurized fluid from within the pipe to the outside via the second flow path.
E21B 47/24 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid by positive mud pulses using a flow restricting valve within the drill pipe
2.
APPARATUS AND METHOD FOR SIGNALLING BETWEEN DOWNHOLE AND UPHOLE LOCATIONS
A downhole tool (12) is deployed from a position entirely within the drill pipe (13) to a position protruding from the pipe by applying pressure to the pipe. The pressure drives the sleeve of a sliding sleeve valve to a position where ports in the wall of the pipe are uncovered so that pressure is vented to generate a high-pressure signal indicating deployment of tool (12).
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
E21B 47/095 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes by detecting acoustic anomalies, e.g. using mud-pressure pulses
3.
APPARATUS AND METHOD FOR SIGNALLING BETWEEN DOWNHOLE AND UPHOLE LOCATIONS
A downhole tool (12) is deployed from a position entirely within the drill pipe (13) to a position protruding from the pipe by applying pressure to the pipe. The pressure drives the sleeve of a sliding sleeve valve to a position where ports in the wall of the pipe are uncovered so that pressure is vented to generate a high-pressure signal indicating deployment of tool (12).
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
E21B 47/095 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes by detecting acoustic anomalies, e.g. using mud-pressure pulses
4.
METHOD OF AND APPARATUS FOR DETERMINING VARIATIONS IN WALL THICKNESS IN FERROMAGNETIC TUBES
A method of determining variations in wall thickness in an elongate, cylindrical, hollow, ferromagnetic tube, such as downhole borehole casing, defining a tube wall, comprises the steps of: a) energizing the tube with an at least longitudinally extending magnetic field generated inside the tube; b) using a magnetic field-detecting logging tool to generate two or more magnetic flux signals generated inside the tube externally of the material of the tube wall resulting from such energizing at plural circumferential locations on the inner surface of the tube and at a plurality of distances along the tube; c) iteratively, one or more times, using a model of the relationship between the two or more magnetic flux signals generated in Step b) and the thickness of the tube wall to derive the thickness profile of the tube wall by using (i) the magnetic permeability of the material of the tube deduced from the magnetic flux signals and (ii) a defect-free flux parameter representative of any non-linearity between the magnetic field strength and magnetic flux density in the tube, the iteration including: d) using the model to calculate an initial approximate wall thickness profile using an initial estimate of the defect-free flux parameter; e) calculating a metric that is representative of the magnitude of one or more physically inadmissible features in or forming part of the thickness profile; f) determining a quantitative norm of the metric of inadmissible features; g) varying the value of the defect-free flux parameter in order to minimize the quantitative norm of the metric of inadmissible features and selecting the defect- free flux parameter corresponding to minimizing of the quantitative norm; and h) generating one or more signals representing the thickness profile resulting from use of selected defect-free flux parameter as the thickness profile of the wall of the tube.
G01B 7/06 - Measuring arrangements characterised by the use of electric or magnetic techniques for measuring length, width, or thickness for measuring thickness
G01N 27/83 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating magnetic variables for investigating the presence of flaws by investigating stray magnetic fields
E21B 47/085 - Measuring diameters or related dimensions at the borehole using radiant means, e.g. acoustic, radioactive or electromagnetic
5.
METHOD OF AND APPARATUS FOR DETERMINING VARIATIONS IN WALL THICKNESS IN FERROMAGNETIC TUBES
A method of determining variations in wall thickness in an elongate, cylindrical, hollow, ferromagnetic tube, such as downhole borehole casing, defining a tube wall, comprises the steps of: a) energizing the tube with an at least longitudinally extending magnetic field generated inside the tube; b) using a magnetic field-detecting logging tool to generate two or more magnetic flux signals generated inside the tube externally of the material of the tube wall resulting from such energizing at plural circumferential locations on the inner surface of the tube and at a plurality of distances along the tube; c) iteratively, one or more times, using a model of the relationship between the two or more magnetic flux signals generated in Step b) and the thickness of the tube wall to derive the thickness profile of the tube wall by using (i) the magnetic permeability of the material of the tube deduced from the magnetic flux signals and (ii) a defect-free flux parameter representative of any non-linearity between the magnetic field strength and magnetic flux density in the tube, the iteration including: d) using the model to calculate an initial approximate wall thickness profile using an initial estimate of the defect-free flux parameter; e) calculating a metric that is representative of the magnitude of one or more physically inadmissible features in or forming part of the thickness profile; f) determining a quantitative norm of the metric of inadmissible features; g) varying the value of the defect-free flux parameter in order to minimize the quantitative norm of the metric of inadmissible features and selecting the defect- free flux parameter corresponding to minimizing of the quantitative norm; and h) generating one or more signals representing the thickness profile resulting from use of selected defect-free flux parameter as the thickness profile of the wall of the tube.
E21B 47/085 - Measuring diameters or related dimensions at the borehole using radiant means, e.g. acoustic, radioactive or electromagnetic
G01B 7/06 - Measuring arrangements characterised by the use of electric or magnetic techniques for measuring length, width, or thickness for measuring thickness
G01N 27/83 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating magnetic variables for investigating the presence of flaws by investigating stray magnetic fields
6.
Method of and apparatus for determining component weight and/or volume fractions of subterranean rock
Component weight and/or volume fractions of subterranean rock are determined. A formation model generates mineral and fluid concentration data from which elemental concentrations are calculated. Forward modeling produces a simulated energy spectrum, and simulation produces a simulated constraining log. Spectra is generated by detecting gamma radiation with a neutron logging tool, and a constraining log is generated. The spectrum and the simulated energy spectrum are compared with resultant error determined. The constraining log and simulated constraining log are compared with resultant error determined. The formation model generates further mineral and fluid concentration to calculate further elemental concentrations. Forward modeling produces further simulated energy spectrum signal and further constraining logs. The spectrum signals and further simulated spectrum signal are compared with resultant error determined. The constraining log and further simulated constraining log are compared, and resultant error is determined. The mineral and fluid concentration are selected that result in minimal error.
G01V 5/10 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using neutron sources
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
G01V 99/00 - Subject matter not provided for in other groups of this subclass
7.
A METHOD OF AND APPARATUS FOR DETERMINING COMPONENT WEIGHT AND/OR VOLUME FRACTIONS OF SUBTERRANEAN ROCK
A method of determining the component weight and/or volume fractions of subterranean rock, comprises the steps of:a. generating or selecting one or more formation model signal representing a formation model listing minerals present in the rock;b. using the one or more formation model signal to generate one or more first formation mineral and fluid concentration data set signal;c. calculating from the one or more first mineral and fluid concentration data set signal one or more first elemental concentration signal representing a first simulated log of elemental concentrations in the rock;d. forward modeling from the one or more elemental concentration signal one or more simulated energy spectrum signal and simulating one or more simulated constraining log signal;e. generating one or more spectrum signal, representing one or more spectra, from detection of gamma radiation resulting from operation of a neutron logging tool in a borehole penetrating the rock and generating one or more constraining log signal representing one or more constraining log;f. comparing the one or more spectrum signal and the one or more first simulated energy spectrum signal, determining the resultant error and generating one or more first error signal indicative thereof;g. comparing the one or more constraining log signal and the one or more first simulated constraining log signal, determining the resultant error and generating one or more first error signal indicative thereof;h. using the one or more formation model signal to generate at least one further formation mineral and fluid concentration data set signal;calculating from the further mineral and fluid concentration data set signal a further calculated elemental concentration signal representing a further simulated log of elemental concentrations in the rock;j. forward modeling from the one or more elemental concentrations one or more further simulated energy spectrum signal and a further simulated one or more constraining log signal representing one or more constraining logs;k. comparing the one or more spectrum signal and the further simulated signal, determining the resultant error and generating one or more further error signal indicative thereof; l. comparing the one or more constraining log signal and the further simulated constraining log signal, determining the resultant error and generating one or more first error signal indicative thereof; andm. selecting the formation mineral and fluid concentration data set that results in a minimal error signal in Steps k. and l..
G01V 5/10 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using neutron sources
A downhole tool connection comprises (i) a tool intended for downhole use and including a connection section protruding therefrom in use in an uphole direction, the connection section supporting two or more first connectors spaced from one another and operatively connected to the tool; and (ii) a cable carrier moveable in an in-use downhole direction towards the connection section. The cable carrier supports (a) one or more cables and (b) two or more second connectors spaced from one another and operatively connected to at least one cable. Pairs of the first and second connectors are mutually connectable, on movement of the cable carrier towards the connection section to increase the proximity of the connectors of the pairs, in a manner effecting electrical transmission between the connectors of each pair. At least one pair of the connectors connects inductively, and at least one pair of the connectors connects conductively.
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
A downhole tool connection comprises (i) a tool (10) intended for downhole use and including a connection section (12) protruding therefrom in use in an uphole direction, the connection section (12) supporting two or more first connectors (16, 17, 18, 19, 21, 22, 23, 24) that are spaced from one another and operatively connected to the tool (10); and (ii) a cable carrier (26) that is moveable in an in use downhole direction towards the connection section (12). The cable carrier (26) supports (a) one or more cables (27) and (b) two or more second connectors (28, 29, 31, 32, 33, 34, 36, 37) that are spaced from one another and operatively connected to at least one said cable (27). Pairs of the first and second connectors are mutually connectable, on movement of the cable carrier (26) towards the tool connection section (12) so as to increase the proximity of the connectors of the pairs, in a manner effecting electrical transmission between the connectors of each pair, wherein at least one pair of the connectors connects inductively and at least one pair of the connectors connects conductively.
E21B 41/00 - Equipment or details not covered by groups
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
10.
IMPROVEMENTS IN OR RELATING TO INDUCTION LOGGING TOOLS
An induction logging tool or logging tool section (10) includes at least one elongate, cylindrical logging tool body (10') having an outer surface (14) of essentially constant outer diameter. The logging tool or logging tool section (10) supports one or more transmitter and/or receiver coils and the outer surface (14) is surrounded by an electrically non- conducting sleeve (16) that is secured relative thereto and of greater external dimensions than the outer surface (14). The sleeve (16) extends outwardly of the outer surface (14) in a manner in use of the logging tool or logging tool section (10) in a borehole excluding borehole fluid from the space occupied by the sleeve (16), such excluding being uninterrupted in all radial directions extending outwardly from the logging tool (10) through the sleeve (16).
G01V 3/28 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device using induction coils
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
11.
Apparatuses and methods for determining properties of subterranean layers
Apparatus (10) for use in determining values of properties of n layers (16,17) of a borehole (11) formed in the Earth's crust (12) comprises a plurality of at least (2n-1) sensor members (19,21,22) of mutually differing, known or calculable, geometric factors, as defined with reference to a sample under investigation comprising n layers. The sensor members (19,21,22) are capable of detecting reflected or transmitted electromagnetic energy and the apparatus (10) includes one or more supports (24,26′) for supporting the sensor members (19,21,22) in a said borehole (11) adjacent and/or in contact with one or more said layers (16,17), the apparatus (10) being capable of causing transmission of electromagnetic energy along, and/or reflection of electromagnetic energy at, each sensor member (19,21,22) in a manner permitting the calculation of values of properties of such layers (16,17) based on reflected or transmitted energy values detected at the sensor members (19,21,22).
G01V 3/20 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with propagation of electric current
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
G01V 3/30 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
G01V 3/28 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device using induction coils
A reflectometer sensor element comprises (i) a recess formed in an electrically conducting material, the electrically conducting material defining a connection portion; the recess including an open end at or adjacent a surface of the electrically conducting material; and a transverse cross-sectional area defined by at least one wall of the recess increasing in at least a first region between the connection portion and the open end; (ii) an electrically conducting electrode that is spaced from the said at least one wall of the recess and extends between the open end and a location proximate the connection portion; and (iii) one or more dielectric materials occupying at least part of the recess between the at least one wall of the recess and the electrically conducting electrode. Such an element allows the detection of signals reflected from deeper within subterranean rock than has previously been possible.
G01V 3/30 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
G01V 3/34 - Transmitting data to recording or processing apparatusRecording data
E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
E21B 47/113 - Locating fluid leaks, intrusions or movements using electrical indicationsLocating fluid leaks, intrusions or movements using light radiation
13.
Fluid pressure waveform generator and methods of use
An acoustic dipole waveform generator has a hollow housing defining an elongate axis and having secured therein at least a force reaction member defining at least a force reaction surface and having hingingly secured thereto an actuator element. The piezoelectric actuator elements define mutually non-aligned length change axes and extend from the reaction member towards at least one moveable piston member hingingly secured to at least one of the actuator elements inside the housing. The piston member is constrained to move in a direction extending perpendicular to the axis, the piston member defining respectively at mutually spaced locations in the housing a pair of heads that, on movement of the piston member, each generate a respective pressure wave and the housing permitting transmission of the wave externally thereby permitting generation of a dipole pressure waveform externally of the housing on changing of the lengths of the actuator elements.
E21B 47/18 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid
G01S 15/88 - Sonar systems specially adapted for specific applications
G01V 1/145 - Generating seismic energy using mechanical driving means by deforming or displacing surfaces
G01S 15/89 - Sonar systems specially adapted for specific applications for mapping or imaging
G01V 1/42 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging using generators in one well and receivers elsewhere or vice-versa
14.
A FLUID PRESSURE WAVEFORM GENERATOR AND METHODS OF ITS USE
An acoustic dipole waveform generator (20, 20', 20", 20"') comprises a hollow housing (19) defining an elongate axis (21) of the acoustic waveform generator and having secured therein at least a first force reaction member (22) defining at least a first force reaction surface (23) and having hingingly secured thereto a first actuator element (24, 26). The piezoelectric actuator elements define mutually non-aligned length change axes (32, 33) and extend from the said first force reaction member (22) towards at least one moveable piston member (34) that is hingingly secured to at least one said actuator element (24, 26) inside the hollow housing (19). The piston member (34) is constrained by one or more constraint members (38, 39) to move in a direction extending perpendicular to the elongate axis (21) of the acoustic waveform generator (20, 20', 20", 20"'), the piston member (34) defining respectively at mutually spaced locations in the housing a pair of piston heads (36, 37) that, on movement of the piston member (34, 36), each generate a respective pressure wave and the hollow housing (19) permitting transmission of each said pressure wave externally of the acoustic waveform generator (20, 20', 20", 20'") thereby permitting generation of a dipole pressure waveform externally of the hollow housing (19) on changing of the lengths of the at least one actuator elements (24, 26).
In acoustic well logging, for each inversion depths of a well at which logging of data occurs, acoustic log signals representative of waveforms received at acoustic receivers are processed in a frequency domain to derive field dispersion curve(s). A neural net is operated to generate formation shear slowness value(s) from the curve(s), and resulting signal(s) indicative of shear slowness values are saved, transmitted, plotted, printed or processed. An apparatus for carrying out the method includes a logging tool having at least one activatable acoustic wave source; spaced and acoustically isolated therefrom in the logging tool an array of acoustic detectors that on the detection of acoustic wave energy generate electrical or electronic log signal(s) characteristic of acoustic energy waves detected by the acoustic detector(s); and at least one processing device associated with or forming part of the logging tool for processing the log signal(s).
A method and a resistivity image logging tool connected or connectable to one or more processing devices process geological log data to construct missing information from destroyed or occluded parts using cues from observed data. The geological log data signals can be generated through use of the logging tool having one or more electrodes interacting with a formation intersected by a borehole. The processing involves the steps of: in respect of one or more data dimensions associated with missing values in a log data set, decomposing the signal into a plurality of morphological components; and morphologically reconstructing the signal such that missing values are estimated.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
G06K 9/00 - Methods or arrangements for reading or recognising printed or written characters or for recognising patterns, e.g. fingerprints
G01V 3/20 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with propagation of electric current
17.
Geological log data processing methods and apparatuses
A method and a resistivity image logging tool connected or connectable to one or more processing devices process geological log data to construct missing information from destroyed or occluded parts using cues from observed data. The geological log data signals can be generated through use of the logging tool having one or more electrodes interacting with a formation intersected by a borehole. The processing involves the steps of: in respect of one or more data dimensions associated with missing values in a log data set, decomposing the signal into a plurality of morphological components; and morphologically reconstructing the signal such that missing values are estimated.
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
G06K 9/00 - Methods or arrangements for reading or recognising printed or written characters or for recognising patterns, e.g. fingerprints
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
A downhole tool coupling (10) comprises first (11) and second (12) downhole tool elements that are securable one to the other in a releasably locking manner by moving the tool elements from a longitudinally relatively less proximate, especially overlapping position into longitudinally relatively more overlap with one another. The first downhole tool element (11) supports a first inductive, capacitative and/or magnetic energy coupler (23) and the second downhole tool element (12) supports a second inductive, capacitative and/or magnetic energy coupler (24). The first and second energy couplers (23, 24) are moveable from an energetically uncoupled position when the tool elements (11, 12) are in the longitudinally relatively less overlapping position to an energetically coupled position when the first and second downhole tool elements (11, 12) overlap relatively more.
E21B 41/00 - Equipment or details not covered by groups
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
A method of optimizing the cross-sectional shape of a logging tool sensor includes the step of, for a given major axis dimension, selecting the minor axis dimension such that for a circular borehole geometry the cross-sectional area of the space between the sensor and a said circular borehole with which the sensor is pressed into contact is minimized. Logging tools optimized according to this technique exhibit beneficial sensor stand-off characteristics.
G01V 11/00 - Prospecting or detecting by methods combining techniques covered by two or more of main groups
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
20.
APPARATUSES AND METHODS FOR DETERMINING PERMITTIVITY IN DOWNHOLE LOCATIONS
Apparatus (57, 58) for determining permittivity in a downhole location comprises a sensor (57) including an elongate conducting line (62) supported on or adjacent a first side of a dielectric substrate (61). The sensor (57) also includes at least one conducting ground element (26, 27) that is spaced from the conducting line (62), the conducting line (62) being capable of juxtaposition to a downhole borehole wall (12). The apparatus further includes connected respectively to spaced locations along the conducting line at least two terminals (31, 32; 63, 64) of a vector network analyser (57b) that is capable of detecting one or more signal reflection characteristics whereby when the sensor (57) is juxtaposed to a borehole wall (12) the vector network analyser (57b) generates one or more signals that are processable to indicate the relative permittivity of rock (39) in which the borehole is formed.
E21B 23/14 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated wells
G01V 3/30 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
A method of processing borehole log data to create one or more image logs involve modelling the log data as components of an image in the form i(x, y)=l(x, y)×r(x, y) (1), in which i(x, y) is an image representative of the log data, l(x, y) denotes an illumination value of the image at two-dimensional spatial co-ordinates x, y, and r(x, y) denotes a surface reflectance value at the co-ordinates x, y. Equation (1) is transformed to a logarithmic domain, and a Fourier transform is obtained of the resulting logarithmic domain expression to obtain a Fourier domain expression. The Fourier domain expression is high-pass filtered, and an inverse Fourier transform is obtained of the resulting filtered Fourier domain expression. An exponential operation is performed on the result of inverse Fourier transform to obtain a filtered image model expression. Values of the filtered image model expression are mapped to respective color values across the range of the filtered image model expression values. The mapped color values can then be displayed, printed, saved and/or transmitted as one or more image logs.
G06T 11/20 - Drawing from basic elements, e.g. lines or circles
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G03B 37/00 - Panoramic or wide-screen photographyPhotographing extended surfaces, e.g. for surveyingPhotographing internal surfaces, e.g. of pipe
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
22.
Communication methods and apparatuses for downhole logging tools
Logging tool communication apparatus (10), for carrying out a downhole communication method, comprises rotatable and/or longitudinally reciprocable drill pipe (12) including fixed or capable of being fixed in a co-rotative and/or co-reciprocable relationship at an in-use downhole end an in-use downhole logging tool (27). The logging tool (27) includes a movement sensor (33); and the apparatus (10) includes a motor, at a location remote from the logging tool (27), for causing rotation and/or reciprocation of the drill pipe (12) in a borehole or wellbore (18). The apparatus (10) includes one or more control elements for selectively controlling operation of the motor so as to cause selective rotation and/or reciprocation of the drill pipe (12) which causes movement of the logging tool (27), when fixed to the drill pipe (12), in a manner that is detectable by the movement sensor (33).
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
23.
COMMUNICATION METHODS AND APPARATUSES FOR DOWNHOLE LOGGING TOOLS
Logging tool communication apparatus (10), for carrying out a downhole communication method, comprises rotatable and/or longitudinally reciprocable drill pipe (12) including fixed or capable of being fixed in a co-rotative and/or co-reciprocable relationship at an in-use downhole end an in-use downhole logging tool (27). The logging tool (27) includes a movement sensor (33); and the apparatus (10) includes a motor, at a location remote from the logging tool (27), for causing rotation and/or reciprocation of the drill pipe (12) in a borehole or wellbore (18). The apparatus (10) includes one or more control elements for selectively controlling operation of the motor so as to cause selective rotation and/or reciprocation of the drill pipe (12) which causes movement of the logging tool (27), when fixed to the drill pipe (12), in a manner that is detectable by the movement sensor (33).
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
A logging tool or sub (10) for downhole use comprises an elongate logging tool body (11); one or more moveable reaction members; and a locking member for the reaction members. At least one arm (12) at a first location is pivotably secured to the body (11) to be extensible therefrom and compressible towards the body (11); and at a second location spaced from the first location is pivotably secured to a locking member (18); and a stop member (22) fixed or fixable relative to the body (11). The locking member (18) defines a moveable end (19) remote from the second location and moveable relative to the arm (12) between at least a first position in which force tending to compress the arm (12) towards the body (11) causes the end (19) to move away from the stop member (22), and a second position in which force tending to compress the arm (12) towards the body (11) causes the stop member (22) to resist movement of the locking member (19) thereby preventing compression of the arm (12) towards the body (11). Alternatively, one or more cam and follower arrangement or rack and pinion arrangement can be used.
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
A logging tool or logging tool sub for downhole use includes an elongate body; one or more moveable reaction members; and a locking member for the reaction members. At least one arm, at a first location, is pivotably secured to the body to be extensible therefrom and compressible towards the body, and at a second location spaced from the first, is pivotably secured to a locking member. A stop member, fixed relative to the body, defines a moveable end remote from the second location and moveable relative to the arm between a first position in which force tending to compress the arm towards the body causes the moveable end to move away from the stop member, and a second position in which force tending to compress the arm towards the body causes the stop member to resist movement of the locking member, preventing compression of the arm towards the body.CA 2914024 2020-03-25
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
26.
Methods of and apparatuses for identifying geological characteristics in boreholes
A method of detecting an edge of a geological characteristic in a borehole comprises, in respect of an image log of a length of a borehole, carrying out the steps of a gradient-based edge detection method, a phase congruence-based edge detection method or a combination of such methods as preliminary, pre-processing stages. Subsequent steps of the method may include operating a relatively computationally simple process to identify sinusoids among detected edge features; and a relatively computationally complex process for parameterizing the thus-identified sinusoids.
G01V 11/00 - Prospecting or detecting by methods combining techniques covered by two or more of main groups
G01V 1/42 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging using generators in one well and receivers elsewhere or vice-versa
G01V 3/24 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with propagation of electric current using AC
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
G01V 3/20 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with propagation of electric current
27.
Methods of and apparatuses for identifying geological characteristics in boreholes
A method of detecting an edge of a geological characteristic in a borehole comprises, in respect of an image log of a length of a borehole, carrying out the steps of a gradient-based edge detection method, a phase congruence-based edge detection method or a combination of such methods as preliminary, pre-processing stages. Subsequent steps of the method may include operating a relatively computationally simple process to identify sinusoids among detected edge features; and a relatively computationally complex process for parameterizing the thus-identified sinusoids.
G01V 11/00 - Prospecting or detecting by methods combining techniques covered by two or more of main groups
G01V 1/42 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging using generators in one well and receivers elsewhere or vice-versa
G01V 3/24 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with propagation of electric current using AC
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
G01V 3/20 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with propagation of electric current
A transmitter for an acoustic logging tool includes an elongated housing, an acoustic energy generator, and a driver. The elongate housing defines a hollow interior and supports an acoustic energy generator, which includes four mutually orthogonally orientated bender bars that are electrically driveable to flex within the hollow interior in order to generate pressure-derived waves in a fluid surrounding the transmitter in use. The housing includes one or more transmissive windows via which flexing of the bender bars gives rise to propagation of one or more said waves in a said fluid. The driver electrically drives the bender bars to flex so as selectively to generate monopole, dipole, or quadrupole waves in a said fluid, with the poles of the dipole and quadrupole when generated selectively being aligned with normals to pairs of the bender bars or rotated 45° relative thereto.
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
G10K 9/12 - Devices in which sound is produced by vibrating a diaphragm or analogous element, e.g. fog horns, vehicle hooters or buzzers electrically operated
A transmitter (30) for an acoustic logging tool (44) comprises: a) an elongate housing (31) defining a hollow interior and supporting an acoustic energy generator, the acoustic energy generator including b) four mutually orthogonally orientated bender bars (33, 34, 36, 37) that are electrically driveable to flex within the hollow interior in order to generate pressure- derived waves in a fluid surrounding the transmitter (30) in use, the housing (31) including c) one or more transmissive windows (42, 43) via which flexing of the bender bars (33, 34, 36, 37) gives rise to propagation of one or more said waves in a said fluid, the transmitter (30) further comprising d) a driver that electrically drives the bender bars (33, 34, 36, 37) to flex so as selectively to generate monopole, dipole or quadrupole waves in a said fluid, with the poles of the dipole and quadrupole when generated selectively being aligned with normals to pairs of the bender bars or rotated 45.degree. relative thereto.
A logging tool or logging tool sub (10) for downhole use comprises an elongate cylindrical body (11) having supported thereby one or more movable landing extensions (12) that are movable between an extended position in which part of each said movable landing extension protrudes beyond the exterior of the cylindrical body (11) so as to define one or more exposed landing surfaces that are engageable with one or more landing surfaces (21) of a further component; and a retracted position in which each said movable landing extension (12) protrudes externally of the cylindrical body no further than the exterior thereof (11).
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
E21B 23/02 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for locking the tools or the like in landing nipples or in recesses between adjacent sections of tubing
E21B 23/14 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated wells
A logging tool or logging tool sub (10) for downhole use comprises an elongate cylindrical body (11) having supported thereby one or more moveable landing extensions(12) that are moveable between an extended position in which part of each said moveable landing extension protrudes beyond the exterior of the cylindrical body (11) so as to define one or more exposed landing surfaces that are engageable with one or more landing surfaces (21) of a further component; and a retracted position in which each said moveable landing extension (12) protrudes externally of the cylindrical body no further than the exterior thereof (11).
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
Disclosed herein is method of computing formation attributes from acoustic measurements in a borehole. The acoustic measurements can be made by operating an acoustic source at multiple frequencies to excite the formation and operating receivers at multiple, longitudinally spaced receiver stations to receive acoustic energy from the formation. The method can include: deriving phase data from the spectrum of received acoustic signals; unwrapping phase information of the phase spectrum data; determining two or more values of difference of phase between acoustic signals at each of a range of frequencies each based on a single generated signal received at two or more pairs of adjacent said receiver stations; generating a value of slope of phase difference values; and in any case of slope ambiguity, unwrapping phase difference information and deriving a dominant slope, at each frequency, from which slowness of the acoustic signal in the formation can be derived.
A method of computing, from acoustic measurements generated from operating an acoustic source to energise at plural frequencies an earth formation penetrated by a borehole and operating receivers defining plural, longitudinally spaced receiver stations to receive acoustic energy altered by the earth formation, one or more formation attributes comprises the steps of: a. deriving phase data from the spectrum of received acoustic signals; b. unwrapping phase information of the phase spectrum data; c. determining two or more values of difference of phase between acoustic signals at each of a range of frequencies each based on a single generated signal received at two or more pairs of adjacent said receiver stations; d. based on Step c. generating a value of slope of phase difference values; and e. in any case of slope ambiguity, unwrapping phase difference information resulting from step d., and deriving a dominant slope, at each frequency, from which is derivable the slowness of the acoustic signal in the earth formation.
A shock absorber (29) for downhole use comprises an elongate, hollow member defined by a series of mutually aligned, plastically deformable perforated members (38) having aligned perforations that define the hollowness of the elongate, hollow member that are spaced from one another in the direction of elongation by respective relatively rigid spacer members (39) that are secured to the perforated members. The elements of each pair of perforated members (38) of the series are so spaced from one another by one or more of the spacer members (39) such that on compression of the shock absorber (29) the perforated members (38) deform plastically to a lesser extent in regions at which the spacer members (39) are secured than at other regions. The arrangement of the perforated members (38) and the spacer members (39) causes compression to occur substantially parallel to the length of the shock absorber (29).
F16F 7/12 - Vibration-dampersShock-absorbers using plastic deformation of members
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
A logging assembly includes a length of drillpipe defining an in-use downhole part, and an elongate toolstring supported by the drillpipe and comprising a plurality of toolstring elements secured seriate one to another. The toolstring is moveable longitudinally relative to the drillpipe between a retracted position lying within the drillpipe and an extended position partly protruding therefrom beyond the downhole extent thereof. The logging assembly includes inside the drillpipe a landing surface having formed therein or defining an aperture through which part of the toolstring moveably extends, and a shock absorber that is capable of acting between the toolstring and the landing surface to attenuate impact energy arising on movement of the toolstring to the extended position and that is engageable with the landing surface to limit movement of the toolstring through the aperture and thereby retain the toolstring moveably captive relative to the drillpipe.
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
E21B 23/14 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated wells
A method of processing borehole log data to create one or more image logs involve modeling the log data as components of an image in the form i(x, y)=l(x, y)×r(x, y) (1), in which i(x, y) is an image representative of the log data, l(x, y) denotes an illumination value of the image at two-dimensional spatial co-ordinates x, y, and r(x, y) denotes a surface reflectance value at the co-ordinates x, y. Equation (1) is transformed to a logarithmic domain, and a Fourier transform is obtained of the resulting logarithmic domain expression to obtain a Fourier domain expression. The Fourier domain expression is high-pass filtered, and an inverse Fourier transform is obtained of the resulting filtered Fourier domain expression. An exponential operation is performed on the result of inverse Fourier transform to obtain a filtered image model expression. Values of the filtered image model expression are mapped to respective color values across the range of the filtered image model expression values. The mapped color values can then be displayed, printed, saved and/or transmitted as one or more image logs.
G06T 11/20 - Drawing from basic elements, e.g. lines or circles
E21B 47/10 - Locating fluid leaks, intrusions or movements
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01V 3/24 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with propagation of electric current using AC
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
A method of processing borehole log data, to create one or more image logs, includes the steps of modelling the data as components of an image, creating multiple versions of the image having respectively differing static scales, and combining the multiple image versions to create a composite image.
A method of processing borehole log data, to create one or more image logs, comprises the steps of:a. modelling the log data as components of an image;b. specifying positional parameters of a virtual light source as azimuthal and elevation angles;c. selecting the set of pixels corresponding to the azimuthal angle:d. computing a one-dimensional derivative of a sub-set of pixels corresponding to this orientation, in which the sub-set is selected based on the elevation angle.;e. shading the image as though the light source illuminates the image at the elevation and azimuthal angles; andf. displaying, printing, saying and/or transmitting the shaded image.
A method of processing borehole log data, to create one or more image logs, comprises the steps of: a modelling the data as components of an image in the form i(x, y) = l(x, y) x r(x, y) (1) in which i(x, y) is an image representative of the log data; l(x, y) denotes an illumination value of the image at two-dimensional spatial co-ordinates x, y; and r(x, y) denotes a surface reflectance value at the co-ordinates x, y; b. transforming Equation (1) to a logarithmic domain; c. obtaining a Fourier transform of the resulting logarithmic domain expression to obtain a Fourier domain expression; d. high-pass filtering the Fourier domain expression; e. obtaining an inverse Fourier transform of the resulting filtered Fourier domain expression; f. performing an exponential operation on the result of Step e. to obtain a filtered image model expression; g. mapping values of the filtered image model expression to respective colour values across the range of the filtered image log expression values; and h. displaying, printing, saving and/or transmitting the mapped colour values as one or more image logs.
A method of detecting an edge of a geological characteristic in a borehole comprises, in respect of an image log of a length of a borehole, carrying out the steps of a gradient- based edge detection method, a phase congruence-based edge detection method or a combination of such methods as preliminary, pre-processing stages. Subsequent steps of the method may include operating a relatively computationally simple process to identify sinusoids among detected edge features; and a relatively computationally complex process for parameterising the thus-identified sinusoids.
A method of detecting an edge of a geological characteristic in a borehole comprises, in respect of an image log of a length of a borehole, carrying out the steps of a gradient-based edge detection method, a phase congruence-based edge detection method or a combination of such methods as preliminary, pre-processing stages. Subsequent steps of the method may include operating a relatively computationally simple process to identify sinusoids among detected edge features; and a relatively computationally complex process for parameterizing the thus-identified sinusoids.
G01V 11/00 - Prospecting or detecting by methods combining techniques covered by two or more of main groups
G01V 1/42 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging using generators in one well and receivers elsewhere or vice-versa
G01V 3/24 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with propagation of electric current using AC
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
G01V 3/20 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with propagation of electric current
42.
Geological log data processing methods and apparatuses
A method of processing geological log data to construct missing information from destroyed or occluded parts using cues from observed data comprises the steps of: a. in respect of one or more data dimensions associated with missing values in a log data set, decomposing the signal into a plurality of morphological components; and b. morphologically reconstructing the signal such that missing values are estimated.
G06K 9/00 - Methods or arrangements for reading or recognising printed or written characters or for recognising patterns, e.g. fingerprints
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
G01V 3/26 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
A method of processing geological log data to construct missing information from destroyed or occluded parts using cues from observed data comprises the steps of: a. in respect of one or more data dimensions associated with missing values in a log data set, decomposing the signal into a plurality of morphological components and b. morphologically reconstructing the signal such that missing values are estimated.
A downhole tool coupling (10) comprises first (11) and second (12) downhole tool elements that are securable one to the other in a releasably locking manner by moving the tool elements from a longitudinally relatively less proximate, especially overlapping position into longitudinally relatively more overlap with one another. The first downhole tool element (11) supports a first inductive, capacitative and/or magnetic energy coupler (23) and the second downhole tool element (12) supports a second inductive, capacitative and/or magnetic energy coupler (24). The first and second energy couplers (23, 24) are movable from an energetically uncoupled position when the tool elements (11, 12) are in the longitudinally relatively less overlapping position to an energetically coupled position when the first and second downhole tool elements (11, 12) overlap relatively more.
A downhole tool coupling (10) comprises first (11) and second (12) downhole tool elements that are securable one to the other in a releasably locking manner by moving the tool elements from a longitudinally relatively less proximate, especially overlapping position into longitudinally relatively more overlap with one another. The first downhole tool element (11) supports a first inductive, capacitative and/or magnetic energy coupler (23) and the second downhole tool element (12) supports a second inductive, capacitative and/or magnetic energy coupler (24). The first and second energy couplers (23, 24) are moveable from an energetically uncoupled position when the tool elements (11, 12) are in the longitudinally relatively less overlapping position to an energetically coupled position when the first and second downhole tool elements (11, 12) overlap relatively more.
Inverting nuclear log data for a geological formation surrounding a borehole involves acquiring nuclear log data for a borehole portion using a moveable nuclear logging tool and acquiring additional log data for the borehole portion using another logging device with superior resolution. Boundaries between adjacent zones are identified that exhibit an attribute of the geological formation to a detectably contrasting degree. From pre-acquired data describing one or more characteristics of the nuclear logging tool, a modeled log of the attributes is generated over the borehole portion, and a zone response is calculated from the pre-acquired data for each zone by using the boundaries to define an initial measure of the depth of each zone and ascribing a value of the attribute in dependence on the depth of each zone. The attribute of each zone is then calculated by deconvolving the nuclear log data using the zone response to minimize the difference between the nuclear log data and the convolution of the zone response and the attribute.
G01V 5/04 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging
G01V 5/06 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging for detecting naturally radioactive minerals
A method of inverting nuclear log data pertaining to a geological formation surrounding a borehole comprises the steps of: (a) acquiring nuclear log data in respect of at least part of the depth of the borehole using a moveable nuclear logging tool; (b) acquiring further log data, in respect of the said part of the depth of the borehole, using a further logging device the depth resolution of which is superior to that of the nuclear logging tool; (c) identifying from the further log data a plurality of boundaries between adjacent zones of the said part of the depth that exhibit an attribute of the geological formation to a detectably contrasting degree; (d) generating from pre-acquired data describing one or more characteristics of the nuclear logging tool a modelled log of the attribute over the said part of the depth; (e) calculating from the pre-acquired data the zone response in respect of each said zone, using the boundaries to define an initial measure of the depth of each zone and ascribing a value of the said attribute in dependence on the said depth of each zone; and (f) calculating the attribute of each zone by deconvolving the log data using the zone response so as to minimize the difference between the log data and the convolution of zone response and zone attribute.
A logging tool, toolstring (10), or element (19) comprises a stabilizer including a pair of moveable, rigid, main stabilizer arms (23, 24) that each is pivotably secured adjacent to one another at one end to the logging tool or toolstring. As a result the arms (23, 24) are moveable between a relatively retracted position on the one hand and a relatively advanced position on the other in which the main stabilizer arms diverge from one another and protrude from the logging tool so as to present a pair of main arm free ends (29, 31) that are spaced from an outer surface of the tool and are engageable with a borehole surface. The logging tool (10) or element (19) includes a mechanism for effecting coordinated, powered, linked movement of the main stabilizer arms (23, 24) between the retracted and advanced positions.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 47/08 - Measuring diameters or related dimensions at the borehole
49.
APPARATUS AND METHODS FOR ORIENTING, STABILISING OR STABLY OPERATING A LOGGING TOOL
A logging tool, toolstring (10) or element (19) comprises a stabiliser including a pair of moveable, rigid, main stabiliser arms (23, 24) that each are pivotably secured adjacent to one another at one end to the logging tool or toolstring. As a result the arms (23, 24) are moveable between a relatively retracted position on the one hand and a relatively advanced position on the other in which the main stabiliser arms diverge from one another and protrude from the logging tool so as to present a pair of main arm free ends (29, 31) that are spaced from an outer surface of the tool and are engageable with a borehole surface. The logging tool (10) or element (19) includes a mechanism for effecting co-ordinated, powered, linked movement of the main stabiliser arms (23, 24) between the retracted and advanced positions.
A logging tool, toolstring (10) or element (19) comprises a stabiliser including a pair of moveable, rigid, main stabiliser arms (23, 24) that each are pivotably secured adjacent to one another at one end to the logging tool or toolstring. As a result the arms (23, 24) are moveable between a relatively retracted position on the one hand and a relatively advanced position on the other in which the main stabiliser arms diverge from one another and protrude from the logging tool so as to present a pair of main arm free ends (29, 31) that are spaced from an outer surface of the tool and are engageable with a borehole surface. The logging tool (10) or element (19) includes a mechanism for effecting co-ordinated, powered, linked movement of the main stabiliser arms (23, 24) between the retracted and advanced positions.
A valve assembly (10) comprises a drillpipe (11) defining a hollow, generally cylindrical interior having secured therein a valve member (12) that is moveable between an open position, permitting passage of an object through the valve (10), and a closed position preventing passage of fluids along the drillpipe (11). A resiliently contractile arm (17) interconnects the valve member (12) and the drillpipe (11) so as to urge the valve member (12) towards the closed position and such that when an object passes along the drillpipe (11) and engages the valve member (12) or the arm (17) the valve member (12) occupies the open position.
E21B 34/06 - Valve arrangements for boreholes or wells in wells
F16K 1/20 - Lift valves, i.e. cut-off apparatus with closure members having at least a component of their opening and closing motion perpendicular to the closing faces with pivoted closure members with pivoted discs or flaps with axis of rotation arranged externally of valve member
F16K 15/03 - Check valves with guided rigid valve members with a hinged closure member
F16K 15/18 - Check valves with actuating mechanismCombined check valves and actuated valves
A valve assembly (10) comprises a drillpipe (11) defining a hollow, generally cylindrical interior having secured therein a valve member (12) that is moveable between an open position, permitting passage of an object through the valve (10), and a closed position preventing passage of fluids along the drillpipe (11). A resiliently contractile arm (17) interconnects the valve member (12) and the drillpipe (11) so as to urge the valve member (12) towards the closed position and such that when an object passes along the drillpipe (11) and engages the valve member (12) or the arm (17) the valve member (12) occupies the open position.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 34/06 - Valve arrangements for boreholes or wells in wells
A method of processing geological log data obtained from use of one or more logging tools and including at least a first log having a relatively poor attribute and a corresponding, second log having a relatively good said attribute comprises the step of incorporating into the first log characteristics of the second log that confer improvements in the said attribute, characterised in that the incorporating step includes modulating the extent of incorporation into the first said log of the said characteristics without distorting geologically significant information in the first log.
An acoustic isolator section for an acoustic well logging tool, the isolator section comprising: an isolator comprising: (i) an isolator body; (ii) a mass; (iii) a resilient portion formed integrally with the isolator body; (iv) a movement limiter.
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