Abstract: A method for modeling deformation in subsurface strata, including defining physical boundaries for a geomechanical system. The method also includes acquiring one or more mechanical properties of the subsurface strata within the physical boundaries, and acquiring one or more thermal properties of the subsurface strata within the physical boundaries. The method also includes creating a computer-implemented finite element analysis program representing the geomechanical system and defining a plurality of nodes representing points in space, with each node being populated with at least one of each of the mechanical properties and the thermal properties. The program solves for in situ stress at selected nodes within the mesh.

Abstract: A system for determining the position of an underground sonde transmitter is disclosed. In some embodiments, the system measures a set of complex electromagnetic field magnitude and phase strengths at one or more positions while traversing a target sonde path at any angle using one or more electromagnetic coil sensors, models a set of expected complex electromagnetic strengths of a hypothetical sonde at the positions for one or more of the electromagnetic coil sensors, the set of expected electromagnetic field values corresponding to a model for the target sonde, and estimates parameters related to the target sonde based on the residual error between the measured set of complex electromagnetic field values and the modeled set of expected complex electromagnetic field strengths. A final estimated parameter set is determined after the residual error has converged to a minimum tolerance to indicate the sonde transmitter position.

Abstract: A method for computing or estimating relative permeability for fractional multi-phase, multi-component fluid flow through a porous medium, which employs a 3D digital representation of a porous medium and a computational fluid dynamics method to calculate flow rates, pressures, saturations, velocities and other flow parameters, is described. The method employs a unique method which integrates a precursor simulation used to generate a set of variables like pressure, saturation and velocity distribution associated with a selected storage plane in the 3D digital representation of a porous medium, which variables are used as inlet condition in the workflow of a second simulation that can generate values of fractional flow rates, pressures, saturations, velocities, or other parameters of wetting and non-wetting phases, which can be used to compute or estimate relative permeability values or other fluid transport properties of the porous medium.

Abstract: An apparatus and method for determining a formation/fluid interaction of a target formation and a target drilling fluid is described herein. The method may include training an artificial neural network using a training data set. The training data set may include a formation characteristic of a source formation and a fluid characteristic of a source drilling fluid and experimental data on source formation/fluid interaction. Once the artificial neural network is trained, a formation characteristic of the target formation and fluid characteristic of target drilling fluid may be input. The formation characteristic of the target formation may correspond to the formation characteristic of the source formation. The fluid characteristic of the target drilling fluid may correspond to the fluid characteristic of the source drilling fluid. A formation/fluid interaction of the target formation and the target drilling fluid may be determined using a value output by the artificial neural network.

Abstract: A passive method for exploring a region below the surface of the earth. The method comprises using a single sensor located in turn at a plurality of locations to obtain seismic data obtained by recording ambient seismic interface waves in a frequency range whose lower limit is greater than 0 Hz, and whose upper limit is less than or equal to substantially 1 Hz. The data are processed so as to obtain a measure of the energy in a frequency band within the frequency range. For example, the seismic data may be filtered and may be subjected to amplitude normalization before being transformed into the frequency domain. The energy measure may then be calculated by integrating the spectrum in the frequency domain over a desired frequency range. The resulting calculated energy provides information about the region of the earth being explored.

Abstract: In one embodiment, a system includes a motion detector to determine a motion event or a no motion event for an inertial system. The determination of the events is based upon comparing at least one motion parameter in the inertial system to at least one predetermined threshold. An azimuth update controller (AUC) periodically requests motion detection events from the motion detector and corrects heading information to a previous positional state in the inertial system in response to receipt of the no motion event.

Abstract: Models of underground formations. At least some of the illustrative embodiments are methods including creating a model of an underground formation. The creating may include: calculating a set of probabilities associated with a first horizontal location, each probability indicative of a likelihood of finding abutting geological layers; estimating a plurality of successions of geological layers to create a plurality of estimated successions, and the estimating using the set of probabilities; determining, for each of the estimated succession, a value indicative of how closely each estimated succession matches a measured succession, the measured succession determined by a seismic survey; and selecting from the plurality of estimated successions based on the values, the selecting creates a selected succession of geological layers, and the plurality of modeled values associated with the first horizontal location determined based on the selected succession of geological layers.

Abstract: A method is presented for modeling reservoir properties. The method includes constructing a coarse computational mesh for the reservoir. The coarse computational mesh comprises a plurality of cells. The method further includes determining a plurality of flows for each of the plurality of cells based on Dirichlet boundary conditions. Additionally, the method includes determining a solution to a coarse pressure equation for the reservoir based on the plurality of flows.

Abstract: A system and method are provided for determining borehole azimuth. The method comprises receiving a first set of data from a first sensor module, the first sensor module comprising a first plurality of accelerometers; receiving a second set of data from a second sensor module, the second sensor module comprising a second plurality of accelerometers, the second sensor module being positioned further downhole than the first sensor module; determining a first set of gravity components using the first set of data and a second set of gravity components using the second set of data; determining a bend angle and a tilt angle using the first and second sets of gravity components; determining a change in azimuth using the bend and tilt angles; and providing an output indicative of the change in azimuth. The system and method may also use a crustal gravity vector to correct the computed azimuth.

Abstract: A method of processing downhole measurement data includes: receiving formation measurement data generated by a downhole tool during a logging-while drilling operation over a selected time period; receiving a measured depth corresponding to the selected time period based on data taken at a surface location; receiving tool rotation data generated by measurements of a rotational rate of the downhole tool taken by a downhole sensor during the selected time period; calculating a new depth of the tool as a function of time over the selected time period based on a relationship between the tool rotation data and the measured depth; and correcting an original depth of the measurement data with the new depth.

Abstract: A method for estimating an inclination and azimuth at a bottom of a borehole includes forming a last survey point including a last inclination and a last azimuth; receiving at a computing device bending moment and at least one of a bending toolface measurement and a near bit inclination measurement from one or more sensors in the borehole; and forming the estimate by comparing possible dogleg severity (DLS) values with the bending moment value.

Abstract: The present disclosure relates to a method to determine a volume of clearance surrounding a wellbore. A logging tool is provided. The logging tool may be disposed on a wireline, a drill string, or a wired drill pipe. A formation property is obtained using the logging tool. The formation property may include a voltage, a bulk resistivity, a horizontal resistivity, a vertical resistivity, a porosity, a permeability, a fluid saturation, an NMR relaxation time, a borehole size, a borehole shape, a borehole fluid composition, an MWD parameter, or an LWD parameter. The maximum depth of investigation into the subsurface formation is determined using a model response and a noise level, and the volume of clearance is determined using the determined maximum depth of investigation. The maximum depth of investigation and volume of clearance may be determined even though no boundary layers are detected.

Abstract: In accordance with one aspect of the present technique, a method is disclosed. The method includes receiving sensor data from a first set of sensors mechanically coupled to a first riser joint of a marine riser. The method also includes analyzing the sensor data to determine a condition of the first riser joint and determining whether the condition satisfies a transmission criterion. The method further includes sending a notification including the condition to an on-vessel monitor communicatively coupled to the marine riser in response to determining that the condition satisfies the transmission criterion.

Abstract: A method for estimating an effect on nuclear magnetic resonance (NMR) measurements of an invasion of solid particles into pores of an earth formation penetrated by a borehole includes conveying a carrier through the borehole and performing an NMR measurement on a volume of interest in the formation to provide a relaxation time constant using an NMR tool disposed at the carrier. The method further includes receiving information describing the solid particles in the pores and quantifying, using a processor, an effect on the measured relaxation time constant due to the invasion of solid particles using the received information.

Abstract: A method for performing contamination monitoring through estimation wherein measured data for optical density, gas to oil ratio, mass density and composition of fluid components are used to obtain plotting data and the plotting data is extrapolated to obtain contamination levels.

Abstract: A telemetry system and method configured to communicate a wellbore parameter such as fluid composition, temperature, and pressure. In one embodiment, a plurality of tracers is stored downhole, and each of the tracers represents a different value of the wellbore parameter. After measuring the wellbore parameter, the measured value is correlated to one or more of the plurality of tracers that is equivalent to the measured value of the downhole parameter. The one or more tracers representing the measured value are then released from their respective containers to travel upstream. A sensor located upstream may detect the one or more tracers, which are then correlated back to obtain the measured value of the wellbore parameter. In another embodiment, ratiometric amounts of the tracers may be used to represent additional values of the wellbore parameter.

Abstract: A method, system and computer-readable medium for obtaining a temperature profile of a wellbore is disclosed. Raw temperature data are obtained from the wellbore using a distributed temperature sensing system. The raw temperature data includes noise. A numerical decomposition is performed on the raw temperature data within a dynamic window in a measurement space of the raw temperature data to obtain decomposition terms of order of first order and higher. An adaptive filter is applied to the decomposition terms of first order and higher within the dynamic window to reduce noise from the decomposition terms of first order and higher. The filtered decomposition terms of first order and higher are used to obtain a temperature profile of the wellbore.

Abstract: In an angle detection method with a resolver, the method being for detecting a rotational angle of a rotator by synchronously detecting a first signal and a second signal that are two phase sine wave modulation signals obtained from a one phase excitation/two phase output resolver, the method includes: a first signal detection process which detects a signal in the order of the first signal and the second signal; and a second signal detection process which detects a signal in the order of the second signal and the first signal.

Abstract: Various embodiments include apparatus and methods to operate to record a plurality of acoustic waveforms, to generate an objective function based on the plurality of acoustic waveforms, and to estimate a global minimum of the objective function. The plurality of acoustic waveforms can correspond to a plurality of acoustic dipole receivers azimuthally disposed around a tool to which the receivers are attached. Additional apparatus, systems, and methods are disclosed.

Abstract: An apparatus and method for well control and monitoring including an independent web server computer integrated with a pump controller located at each well in an oil field. The well controller locally controls the well pump, processes well and pump data, generates surface and downhole cards, and communicates production reports, recommendations for production improvements, and production statistics to remote sites via the internet. The controller can be queried remotely to provide production reports, etc. Furthermore, the controller can initiate alerts via email, text messaging, or internet messaging, for example, during fault conditions.

Abstract: Systems, methods and devices for evaluating a condition of a downhole component of a drillstring. Methods include estimating a value of a tool parameter of the component at at least one selected position on the drillstring; and using the estimated value to evaluate the condition of the downhole component. The estimating is done using a trained artificial neural network that receives information from at least one sensor that is positionally offset from the selected position. The method may further include creating a record representing information from estimated values of the tool parameter at the at least one selected position over time. The at least one selected position may include a plurality of positions, such as positions at intervals along the component, including substantially continuously along the component.

Abstract: In some embodiments, an apparatus and a system, as well as a method and an article, may operate to determine spatial orientations of one or more transmitters attached to a first downhole component, relative to one or more receivers attached to a second downhole component, at common points in time during rotation of the first and the second downhole components. The first downhole component may be variably, rotationally coupled to the second downhole component. Further activity may include transforming raw measurements of transmitter signals provided by the receiver(s) into calibrated measurements based on the spatial orientations at the common points in time. Additional apparatus, systems, and methods are described.

Abstract: A system and method to synchronize distributed measurements in a borehole are described. The system includes a plurality of wired segments coupled together by couplers and a plurality of nodes configured to measure, process, or relay information obtained in the borehole to a surface processing system, each of the plurality of nodes comprising a local clock and being disposed at one of the couplers or between couplers. The system also includes a surface processing system coupled to a master clock and configured to determine a time offset between the master clock and the local clock of an nth node among the plurality of nodes based on a downhole generated synchronization signal.

Abstract: A system and method for use in a downhole tool having distance measurement, feature detection, and primary measurement devices positioned therein are provided. In one example, the method includes recording a first plurality of features and corresponding positions in a first log using the feature detection device and the distance measurement device, respectively. A first feature of the first plurality of features is selected and the position corresponding to the first feature is identified. The feature detection device is aligned relative to the first feature based on the identified position. A first primary measurement is taken using the primary measurement device while the feature detection device is aligned relative to the first feature. The steps of recording, selecting, moving, and taking are repeated to obtain a second primary measurement while the feature detection device is aligned relative to a second feature of a second plurality of features.

Abstract: A method and system are provided for heterogeneous log analysis. The method includes performing hierarchical log clustering on heterogeneous logs to generate a log cluster hierarchy for the heterogeneous logs. The method further includes performing, by a log pattern recognizer device having a processor, log pattern recognition on the log cluster hierarchy to generate log pattern representations. The method also includes performing log field analysis on the log pattern representations to generate log field statistics. The method additionally includes performing log indexing on the log pattern representations to generate log indexes.

Abstract: Four or more seismic attributes are integrated or merged into imaging formats and displayed for geological interpretation via extended quantization. Multi-attribute integration and classification improves the ability to identify geologic facies, and reservoir properties such as thickness, fluid type, or fracture intensity and orientation. The extended quantization groups up to eight attributes as a single attribute for geophysical data classification. Data group reduction criteria are provided to reveal common geological targets in the data, while preserving small variations or thin layers often found in hydrocarbon reservoirs. By combining multiple attributes, image quality is enhanced while providing analysts the ability to observe channels that might not be visible in any single attribute.

Abstract: A method for performing a field operation of a field having a subterranean formation. The method includes analyzing, by a computer processor, a plurality of training well logs of a plurality of training wells in the field to generate a plurality of training well markers, wherein the plurality of training well markers identify where the plurality of training wells intercept a plurality of geologic interval boundaries in the subterranean formation, propagating, by the computer processor and onto a target well log of a target well in the field, the plurality of training well markers to generate a plurality of target well markers, wherein the plurality of target well markers identify where the target well intercepts the plurality of geologic interval boundaries, and performing the field operation based at least on identifying where the target well intercepts the plurality of geologic interval boundaries.

Abstract: Systems and related methods to simulate, predict, and report progressive failures of rupture disks in response to thermal expansion of trapped annular fluids.

Abstract: Wavelet estimation method, particularly advantageous for full wavefield inversion (“FWI”) of seismic data, that makes use of both the primary and multiple reflections in the data. The inventive method uses an FWI algorithm to generate a subsurface model from primary reflections (101) in a shallow layer before first arrival of multiple reflections (101). The model is then used to simulate multiples (102). The wavelet is subsequently modified (104) such that the simulated multiples closely match the true recorded multiples (103). The simulated multiples may then be subtracted from the measured data (105) thereby creating a deeper top layer of data substantially free of multiples, and the method may then be repeated to extend the subsurface model to a greater depth (106).

Abstract: Planning and/or drilling wellbores. At least some of the various embodiments are methods including: receiving data indicative of position of a first wellbore; reading data indicative of position of an offset wellbore; reading data indicative of a fracture diameter for the offset wellbore; calculating a first positional uncertainty of the first wellbore; calculating a second positional uncertainly of the offset wellbore taking into account the data indicative of position and the data indicative of fracture diameter; and generating a value indicative of proximity of the positional uncertainties.

Abstract: A system and method for use in a downhole tool having a fluid density measurement device positioned therein are provided. In one example, the method includes deploying the downhole tool at a first station in a borehole. The downhole tool is moved from the first station to a second station in the borehole. A plurality of fluid density values of fluid within the borehole between the first and second stations are measured using the fluid density measurement device in the downhole tool. The plurality of fluid density values may represent a continuous log of fluid densities between the first and second stations.

Abstract: Data transmission from a bottom hole assembly (BHA) includes obtaining a scan from multiple scans forming a downhole data log of a borehole within a subterranean formation. The scan includes a sequence of data items from a sensor in the BHA located in the borehole. Each data item corresponds to an azimuth angle of the sensor. Further, compressed scan data is generated from the sequence of data items on a per-scan basis, and transmitted, using a pre-determined borehole telemetry, to a surface unit.

Abstract: A method for acquiring and processing wellbore measurements includes measuring at least one wellbore parameter. The measured wellbore parameters are communicated to a data hub. A computer in signal communication with the data hub automatically processes the measured wellbore parameter using a predefined automatic process. The automatically processed measured wellbore parameter is communicated to at least one user interface based on assigned tasks of a user interacting with the at least one user interface with respect to a wellbore construction procedure.

Abstract: Formation evaluation measurements are used to estimate formation lithology. The estimated lithology is used to provide an estimate of acoustic wave slowness. The estimated acoustic wave slowness is used to provide processing parameters for acoustic data that are less sensitive to noise.

Abstract: Disclosed is a method for detecting a pair of opposing breakouts in a borehole penetrating an earth formation. The method includes: conveying a downhole tool configured to perform measurements of a property of the earth formation; producing an image of the earth formation from the measurements, the image comprising a plurality of sectors; dividing the sectors into radial segments, each segment corresponding to an opposite segment; rotating the segments at least one sector at a time until a specified angle is achieved; calculating an average value for the measurements associated with each segment for each rotation of the segments; stacking the average values for opposing segments to produce stack values; determining a maximum or minimum stack value; determining if the maximum or minimum stack value exceeds a threshold value; and detecting the first breakout and the second breakout if the maximum or minimum stack value exceeds the threshold value.

Abstract: The apparatus employs the remote field eddy-current (RFEC) inspection technique to electromagnetically measure physical parameters of a metallic pipe. RFEC devices inserted into and displaced along a cylindrical pipes may be used to measure the ratio of pipe thickness to electromagnetic skin-depth and thus allow for the non-invasive detection of flaws or metal loss. Typically these RFEC thickness measurements exhibit a so-called double-indication of flaws, an undesired artifact due to a double-peaked geometrical sensitivity function of the device. The method describes a means by which this double indication artifact may be removed by an appropriate processing of RFEC measurements performed by an apparatus specifically designed for this purpose. The invention is particularly well designed for applications in the oilfield industry.

Abstract: Methods and systems for characterizing a formation are disclosed. A tool is placed in the formation. The tool comprises a perpendicular antenna set and a parallel antenna set. The perpendicular antenna set comprises at least one transmitter antenna oriented perpendicular to at least one receiver antenna and the parallel antenna set comprises at least one transmitter antenna oriented parallel to at least one receiver antenna. Data is obtained from the tool and used to determine a compensated geosignal for each of the perpendicular antenna set and the parallel antenna set. The determined compensated geosignal is used to characterize the formation.

Abstract: A method, and corresponding system, for formation testing includes establishing a control parameter and a test criterion for testing a formation, providing a formation tester equipped with the control parameter and the test criterion in a well bore at a test location, performing a first formation test, controlling the first formation test using the control parameter and the test criterion, collecting test data from the first formation test, and adjusting the control parameter using the test data. The method may include performing a second formation test, and controlling the second formation test using the adjusted control parameter and the test criterion. The method may include collecting additional test data from the second formation test, and readjusting the control parameter using the additional test data.

Abstract: A method of estimating influx profile for well fluids (oil, gas, or water) to petroleum well with influx locations to a production flow, including: arranging tracer sources with tracer materials in levels of the well, arranged downstream and exposed to the fluids in the influx zones, each of the tracer sources having even release rate to the well fluid, inducing a transient in the production rate of the entire production flow by shutting in by a valve topside, changing the local exposure times of the tracer sources to the fluid, collecting samples, downstream at known sampling times, analyzing the samples for concentration and type of tracer material from the possible sources, based on the concentrations and their sampling sequence and the well geometry, calculating influx volumes from flow models.

Abstract: An apparatus, method and computer-readable medium for locating a joint of a casing disposed in a borehole are disclosed. The apparatus includes a sensor oriented in a plane orthogonal to a longitudinal axis of the casing. The sensor measures a magnetic field induced in the casing by the earth's magnetic field. A tool conveys the sensor through the casing along a path that is radially offset from a longitudinal axis of the casing. Transverse magnetic field measurements are obtained by the sensor at a plurality of depths along the casing. A change in the transverse measurements is identified and used to determine the location of the casing joint.

Abstract: A method and a system are provided for determining the relative positions of a wellbore and an object. The wellbore is represented by a first ellipse and the object is represented by a second ellipse. The first ellipse represents the positional uncertainty of the wellbore and the second ellipse represents the positional uncertainty of the object. The method includes receiving input data relating to a measured or estimated position of the wellbore and the object. In addition, the method includes calculating an expansion factor representing an amount by which one, or both, of the first ellipse and the second ellipse can be expanded with respect to one or both of respective first and second sets of elliptical parameters so that the first and second ellipses osculate. Further, the method includes determining, based on the calculated expansion factor, position data indicative of the relative positions of the wellbore and the object.

Abstract: Enhancing resolution of distributed optical measurements along a wellbore can include acquiring optical signals during an acquisition time period, thereby producing a convolved profile along the wellbore, and deconvolving the profile using a first function corresponding to the acquisition time period, thereby determining a second function. Another method of enhancing resolution of distributed temperature measurements along a wellbore can include acquiring optical backscatter signals during at least first and second acquisition time periods, thereby producing respective first and second convolved temperature profiles along the wellbore; deconvolving the first temperature profile using a first function corresponding to the first time period, thereby determining a second function; and deconvolving the second temperature profile using the second function, thereby determining the first function corresponding to the second time period.

Abstract: Downhole tools and techniques acquire information regarding nearby conductors such as pipes, well casing, and conductive formations. At least some method embodiments provide a current flow along a drill string in a borehole. The current flow disperses into the surrounding formation and causes a secondary current flow in the nearby conductor. The magnetic field from the secondary current flow can be detected using one or more azimuthally-sensitive antennas. Direction and distance estimates may be obtainable from the azimuthally-sensitive measurements, and can be used as the basis for steering the drillstring relative to the distant conductor. Possible techniques for providing current flow in the drillstring include imposing a voltage across an insulated gap or using a toroid around the drillstring to induce the current flow.

Abstract: A system comprising a piece of oilfield equipment, an identifier assembly and a reader. The piece of oilfield equipment has an exterior surface. The identifier assembly comprises an identification tag storing a unique identifier. The identification tag is capable of outputting a signal indicative of the unique identifier. The identification tag is mounted to the exterior surface of the piece of oilfield equipment beyond an external surface perimeter of the piece of oilfield equipment such that the identification tag is isolated from the exterior surface of the piece of oilfield equipment. The reader has an antenna receiving the signal indicative of the unique identifier from the identification tag.

Abstract: A method and a tool that implements a method which includes measuring the viscosity and flow rates of formation fluids and obtaining the ratio of relative permeabilities of the formation fluids and wettability of the formation using the same.

Abstract: A system for calculating the radius of investigation of a radial, composite reservoir, comprises a processor; a memory and, preferably, a clock electronically coupled to the processor; a display electronically coupled to said processor; and an electronic input coupled to said processor. The processor is programmed to calculate the radius of investigation, at any given time, in the reservoir based upon a plurality of user inputs including the number of concentric regions n into which the reservoir is to be divided, a starting time or elapsed time, and data relating to the reservoir rock, fluids, and geometries of each of the n regions. The processor computes the radius of investigation using at least one of Equations (1), (2) and (6) through (12) set forth in the specification, if using the System of U.S. Oilfield Units, or using an equivalent equation if using other units.

Abstract: Prospect assessment and play chance mapping tools are provided. For assessing potential resources, example systems provide dynamically linked chance maps, transformed in real time from geological properties. Input geological maps or other data are dynamically linked to resulting chance maps, so that changes in the input maps automatically update the chance map in real time. Users can generate a custom risk matrix dynamically linking geological maps with chance maps via interface tools, dropping maps directly into the matrix. A transform may programmatically convert the geologic domain to the chance domain. The user can navigate input maps, select areas of interest, and drag-and-drop geologic properties into an uncertainty engine and distribution builder for uncertainty assessment based on geologic reality. A merge tool can programmatically unify multiple geological interpretations of a prospect. The merge tool outputs a single chance of success value for multiple geologic property values at each grid node.

Abstract: The disclosure provides a method which includes transmitting signals over a time period between a downhole location and a surface location during drilling of a wellbore; recording the time of each signal at the surface using a surface clock and the time of each signal downhole using a downhole clock; and correcting the downhole measurements using the recorded times.

Abstract: A method for water monitoring about a deviated well is disclosed. The method includes positioning a series of electromagnetic (EM) receivers in a completed deviated wellbore, said receivers being spaced along substantially the length of the well located in a region of a reservoir to be monitored. The method also includes positioning an electromagnetic (EM) source at a first Earth surface location. Then the EM source is activated for a first survey measurement of the reservoir, and an EM field detected at each EM receiver is recorded. The EM source is moved to a second Earth surface location, and activated for a second survey measurement of the reservoir, and an EM field detected at each EM receiver is recorded. From the first and second survey measurements at each of the receivers, an inversion is performed to determine position of water about (and specifically below) the horizontal well.

Abstract: A method of mapping a subterranean formation having at least one wellbore therein may include operating an electromagnetic (EM) signal source and an EM receiver to generate wellbore position data. The method may also include operating a seismic signal source and a seismic receiver to generate seismic data, and generating subterranean formation data based upon the wellbore position data and the seismic data.