Abstract: A method for performing field operations is disclosed. The method includes obtaining a first set of acoustic radial profiles of a subterranean formation prior to induction of a fracture disposed about the wellbore, obtaining a second set of acoustic radial profiles of the subterranean formation subsequent to the induction of the fracture, comparing the first set of acoustic radial profiles and the second set of acoustic radial profiles based on a pre-determined criterion to generate a comparison result, determining, based on the comparison result, an orientation of one or more portions of the fracture, and adjusting the operations of the oilfield based on the orientation.

Abstract: A method and apparatus for sensing conditions in a subsurface geologic formation heated for the extraction of hydrocarbons is disclosed. A time domain reflectometer in conjunction with an open wire transmission line is employed in real time to determine impedance discontinuities in the geologic formation. These impedance discontinuities correspond to physical conditions in the geologic formation. The open wire transmission line can include pipes running into the subsurface geologic formation or other conductors, including a split tube well casing. The method may operate in the low frequency window for subsurface electromagnetic propagation.

Abstract: A method of passive surveying comprises generating one or more detected signals by passively detecting a signal generated within a subsurface earth formation due to a seismoelectric response or an electroseismic response in at least one porous subsurface earth formation containing at least one fluid, and processing the one or more detected signals to determine at least one property of the subsurface earth formation.

Abstract: The present disclosure relates to borehole logging methods and apparatuses for estimating a parameter of interest of an earth formation using logging data acquired in a borehole penetrating the earth formation. The method may include estimating the at least one parameter of interest using a statistical analysis of logging data acquired by at least one sensor, wherein the statistical analysis is applied over interval plurality of intervals within the logging data. The logging data may include one or more of: gamma ray data and spontaneous potential data. The method may include acquiring logging data with the at least one sensor. The method may also include estimating a confidence level for the at least one estimated parameter. The apparatus may include at least one sensor configured to generate logging data information about an earth formation; and at least one processor configured perform at least some of the steps of the method.

Abstract: A method and computer-readable medium for determining a scattered wave particle velocity for a formation is disclosed. In aspects, the method may include: defining an embedded grid of the formation, and defining a contrast grid of the formation that includes a contrast feature of the formation; calculating a Green's function over the embedded grid; calculating a first scattering vector of the contrast feature for a first offset between the embedded grid and the contrast grid; determining the scattered wave particle velocity for the contrast feature at the first offset using the calculated Green's function and the first scattering vector; calculating a second scattering vector of the contrast feature for a second offset between the embedded grid and the contrast grid; and determining the scattered wave particle velocity for the contrast feature at the second offset is determined using the calculated Green's function and the second scattering vector.

Abstract: Method for deriving a reservoir property change data volume from time shifts used to time-align 4D seismic survey data (31). The time alignment is performed on at least one angle stack of 4D data to determine a time-shift data volume (32). When multiple angle stacks are used, the time shifts are corrected to zero offset. A running time window is defined, and within each window the time shifts are best fit to a straight-line function of time (depth), one angle stack at a time (33). The slopes from the straight line fits from different angle stacks are averaged at each voxel in the data volume, which yields a reservoir properties (?v/v) data volume (34). This data volume may be filtered with a low-pass filter to improve signal-to-noise (35). The resulting data volume may be merged with the 4D data volume to expand its bandwidth (36), or it may be converted into a reservoir saturation and pressure change data volume (38) using a rock-physics model (37).

Abstract: Methods for managing an intelligent field, are provided. An exemplary method can include receiving real-time dynamic field data, analyzing validity of the dynamic field data, validating values of the field data, validating a state/condition of a well, and flagging well components, well conditions, and/or well state validation issues.

Abstract: Apparatus and computer readable media for managing an intelligent field, are provided. An exemplary apparatus can include hydrocarbon well instruments, a SCADA system, a process integration server and/or dynamic field data analyzing computer, and memory/computer readable media storing a dynamic field data analyzing computer program. The computer program can include instructions that when executed cause the dynamic field data analyzing computer to perform various operations to include receiving real-time dynamic field data, analyzing validity of the dynamic field data, validating values of the field data, validating a state/condition of a well, and flagging well components, well conditions, and/or well state validation issues.

Abstract: Fluid tests may be performed to determine suitability of an additive for a production enhancement treatment. In one aspect, a measuring device is used to determine a result of adding a sample of solid material to a test fluid that includes an additive. The result may include, for example, a change in surface tension, a change in contact angle, and/or another result. The measured result is used to determine the suitability of the additive for use in a stimulation treatment for a subterranean formation. For example, the additive may be determined suitable for use during a pad phase of a fracture treatment, during a proppant-laden phase of a fracture treatment, and/or for other phases and/or types of stimulation treatments.

Abstract: A method of passive surveying comprises generating one or more detected signals by passively detecting a signal generated within a subsurface earth formation due to a seismoelectric response or an electroseismic response in at least one porous subsurface earth formation containing at least one fluid, and processing the one or more detected signals to determine at least one property of the subsurface earth formation.

Abstract: A best fitting trace in seismic data is determined for a desired trace to be reconstructed. A dip-based correction is calculated per trace and per sample for differences in azimuth, common midpoint coordinates, and offset between the best fitting trace and the desired trace. The dip-based correction is applied to the best fitting trace to reconstruct the desired trace for 3D surface-related multiple prediction.

Abstract: Various embodiments include apparatus and methods to operate with respect to environmental measurements. Apparatus and methods include a processing unit to generate a ratio from signals measured relating to an underground environment and to determine parameters of the underground environment based on the generated ratio.

Abstract: A method for determining permeability of a reservoir using a packer-probe formation testing tool. The elements of the method include generating, using a dual packer tool module, fluid flows from the reservoir into a wellbore, obtaining pressure data associated with the fluid flows using an observation probe tool module, wherein the packer-probe formation testing tool comprises the dual packer module and the observation probe tool module, identifying a portion of the pressure data corresponding to a spherical flow regime, determining horizontal permeability based on the portion of the pressure data, and displaying an output generated using the horizontal permeability.

Abstract: A method for processing well logging data includes method dividing the well logging data into a number of constant dimensional effect segments, where each constant dimensional effect segment defines an interval having a similar dimensional effect on the log response. The well logging data is taken from a highly deviated well. The method further includes dividing the constant dimensional effect segments into a number of constant property intervals, each constant dimensional effect segment including at least one corresponding constant property interval, and each constant property interval defining a wellbore distance over which a formation property is substantially constant that results in a log response having a low variance. The method further includes providing the constant property intervals to an output device.

Abstract: A directional resistivity tool includes a pair of transmitters deployed between at least one pair of receivers. Each of the transmitters and receivers preferably includes collocated z-mode and x-mode antennae. Exemplary embodiments may further include additional receivers, for example, additional pairs of receivers deployed axially about the transmitters or one or more deep reading receivers deployed on one axial end of the transmitters. Tools in accordance with the invention enable directional resistivity measurements to be acquired at multiple depths of investigation using fewer transmitter firings than conventional tools.

Abstract: A methodology for reservoir understanding employs analysis of fluid property gradients to investigate and distinguish between non-compartmentalization of the reservoir, compartmentalization of the reservoir, and lack of thermodynamic equilibrium in the reservoir.

Abstract: The disclosure is related to methods for determining a stress-deformed state of layered media having at least one fluid-filled poroelastic layer induced by fluid pressure changes and it can be used in oil & gas industry. The method comprises determining initial parameters of a layered medium and a volume-distributed loading of developed layers of the layered medium. Then a set of equations is specified including elastic balance equations for each layer and equations defining boundary conditions between the layers. Analytical solutions of the elastic balance equations for each layer are obtained and adjusted to satisfy boundary conditions between the layers. Displacements and stresses in any point of the layered medium are determined in accordance with a required approximation accuracy on basis of the adjusted analytical solutions.

Abstract: A system for geosteering during directional drilling of a wellbore including a processor, a data storage, and client devices in communication with the processor through a network. The processor can receive data from directional drilling equipment and can present that data to users in an executive dashboard. Users can send data and/or commands to the directional drilling equipment. The executive dashboard can present: a portion of interest in a stratigraphic cross section for user identification of: the drill bit in the stratigraphic cross section, formations in the stratigraphic cross section, and other formation data. The system can be used to: identify a projected path for the drill bit, import data, compute wellbore profiles and stratigraphic cross sections, plot actual drilling paths, overlay the actual drilling path onto the projected path, and present control buttons to the user.

Abstract: A method for geosteering during directional drilling of a wellbore including a processor, a data storage, and client devices in communication with the processor through a network. The processor can receive data from directional drilling equipment and can present that data to users in an executive dashboard. Users can send data and/or commands to the directional drilling equipment. The executive dashboard can present a portion of interest in a stratigraphic cross section for user identification of the drill bit in the stratigraphic cross section, formations in the stratigraphic cross section, and other formation data. The method can be used to identify a projected path for the drill bit, import data, compute wellbore profiles and stratigraphic cross sections, plot actual drilling paths, overlay the actual drilling path onto the projected path, and present control buttons to the user.

Abstract: A method for characterizing fracture planes generated during a hydraulic fracturing process, comprises receiving microseismic data from the hydraulic fracturing process and processing a microseismic event cloud from the received microseismic data. This is followed by determining at least one reservoir geometry from the microseismic event cloud. The determination of geometry may consist of determining multiple candidate geometries and probability of each. In some forms of the invention the method may comprise postulating a set of candidate geometries with differing numbers of fracture planes, determining the most probable locations of the postulated fracture planes in each member of the set of candidate geometries and also determining relative probabilities of the candidate geometries in the postulated set. Determining a location of a fracture plane may comprise calculating a number density for each microseismic event, dependent on distance from some possible location of a fracture plane or fracture network.

Abstract: A method and system for producing look-ahead profiles measurements includes positioning an energy transmitter, such as a transmitting antenna, proximate to a borehole assembly tool. One or more energy receivers, such as receiving antennas, are positioned along a length of the borehole assembly. Next, energy is transmitted to produce look-ahead scans relative to the borehole assembly tool. Look-ahead graph data with an x-axis being a function of a time relative to the position of the borehole assembly tool is generated. The look-ahead graph is produced and displayed on a display device. The look-ahead graph may track estimated formation values based on earth models. The estimated formation values are displayed below a tool position history line that is part of the look-ahead graph. The estimated formation values in the look-ahead graph may be based on inversions of resistivity data from the look-ahead scans.

Abstract: Various embodiments include apparatus and methods of operation with respect to well logging. Apparatus and methods include a tool having an arrangement of transmitters and receivers that are operated at different positions downhole and a processing unit to process collected signals such that the arrangement of transmitters and receivers provides measurements that mimic operation of a different arrangement of transmitters and receivers. Additional apparatus, systems, and methods are disclosed.

Abstract: A method of passive surveying comprises generating one or more detected signals by passively detecting a signal generated within a subsurface earth formation due to a seismoelectric response or an electroseismic response in at least one porous subsurface earth formation containing at least one fluid, and processing the one or more detected signals to determine at least one property of the subsurface earth formation.

Abstract: A method for performing seismic interpretation of a subterranean formation by enabling dual-domain interpretation of seismic features in the present day depth domain and simultaneously in a structurally restored “mapped” seismic domain. Specifically, seismic interpretation is performed on structurally restored seismic volumes while concurrently viewing the interpretation results in the structural domain. This increases the interpretation confidence by improved correlation of structural deformed events to their pre-structurally deformed geometry. The method includes the ability to progressively remove structural deformation from the seismic volume, corresponding to moving back in geologic time. The interpretation can be performed in either domain (present-day structure or structurally restored to a defined geologic event), and the interpretation will be mapped to any other computed geologic age or present structural age.

Abstract: A system for determining at least one of a lithology of a formation traversed by a borehole and an operational condition of a component of a drill string disposed in the borehole is disclosed. The system includes a drill string with a high speed wired pipe telemetry system for transmitting downhole measurements made by a sensor to a computer processing system in real time. The computer processing system is external to the drill string and includes a model that models operation of the drill string and/or a formation that is being drilled. The model receives the downhole measurements and surface measurements of a drilling parameter and provides as output detection of the lithology of the formation and/or the operational condition of the component.

Abstract: A system and a method, implemented on a computer, for calculating property distribution uncertainty of spatially correlated petrophysical data. The method includes inputting, into the computer, a sample petrophysical data comprising correlated data; applying, using the computer, a variogram to the sample petrophysical data to select a plurality of subsets of data, the subsets of data being substantially less correlated than the sample petrophysical data; and applying, using the computer, a bootstrap process on each of the plurality of subsets of data to obtain a plurality of bootstrap data sets from each of the plurality of subsets of data. The method further includes calculating data distributions for each of the obtained plurality of bootstrap data sets; ranking the data distributions by using a selected statistical parameter to obtain ranked data distributions; and characterizing the uncertainty based on the ranked data distributions.

Abstract: The present disclosure relates to a method to determine a characteristic of a subsurface formation using a downhole logging tool. A downhole logging tool having the ability to make substantially concurrent disparate measurements on the subsurface formation is provided and substantially concurrent disparate measurements on the formation using the downhole logging tool are made. Those measurements are used to solve a system of equations simultaneously and the solution to the system of equations is used to determine the characteristic of the subsurface formation.

Abstract: Various methods are disclosed, comprising obtaining a plurality of raw depth measurements for a wellbore; obtaining survey data about a bottom hole assembly; obtaining depth compensation information; calculating a plurality of compensated depth measurements from the raw depth measurements and the depth compensation information and one or more additional corrections for residual pipe compliance, tide, and rig heave; calculating sag angle and correcting the survey data with the sag angle; determining a high fidelity wellbore trajectory from the compensated depth measurements and the survey data; and then employing the high fidelity wellbore trajectory in various drilling, formation evaluation, and production and reservoir analysis applications. Depth compensation information may comprise at least one of weight on bit, a friction factor, temperature profile, borehole profile, drill string mechanical properties, hookload, and drilling fluid property. The surveys may include both static and continuous surveys.

Abstract: Systems, methods, and instructions encoded in a computer-readable medium can perform operations related to generating probabilistic information on characteristics of natural fractures of a subterranean formation. Fitted fracture models are generated based on microseismic event data for a subterranean region. The fitted fracture models represent estimated locations of fractures in the subterranean region. A distribution of fracture parameter values is generated based on the fitted fracture models. The distribution includes fracture parameter values and a probability associated with each fracture parameter value. Generating the fitted fracture models may include, for example, fitting a plane, a line or another type of equation to the measured locations of microseismic events. In some implementations, an injection treatment may be simulated and/or designed based on the probability distribution.

Abstract: Apparatus for in-situ wellbore measurements, said apparatus comprising one or more sensors arranged outside a wellbore, one or more actuators associated with the sensors, an electromagnetic transceiver situated inside a non-magnetic portion of wellbore conduit and mounted on an electric-line logging cable, a downhole interface unit also located on the electric-line cable for controlling communication to the apparatus. Also a method of in-situ wellbore measurements using said apparatus.

Abstract: Methods and apparatus to control a formation testing operation based on a mudcake leakage are disclosed. A disclosed example method for use with a downhole tool disposed in a wellbore comprises measuring a property of a mudcake layer at a first location in a wellbore, determining a value representative of an estimated leakage through the mudcake layer based on the property, and determining, based on the value, whether to continue a formation testing operation.

Abstract: A method is disclosed including simulating a hydraulic fracture in an Earth formation, the formation including a multilayered reservoir, wherein a mesh overlays the hydraulic fracture thereby defining a plurality of fracture elements. The method further includes calculating and determining an influence coefficient matrix having spatially related indices, wherein the spatially related indices relate influence coefficient matrix elements to corresponding fracture elements. The mesh overlays the hydraulic fracture in more than one layer of the multilayered reservoir. In one embodiment, the method is executed on a program storage device readable by a machine tangibly embodying a program of instructions executable to perform the method.

Abstract: According to various embodiments, a method may include measuring a first capacitance of a sample at a first frequency using a measurement system, measuring a second capacitance of the sample at a second frequency using the measurement system, calculating a ratio of the first capacitance to the second capacitance, and determining a formation water resistivity or conductivity of the sample using the ratio.

Abstract: A technique for processing well logs performs a nonlinear resolution enhancement of raw well logs. The nonlinear enhancement procedure uses a modified Van Cittert nonlinear enhancement technique that avoids instabilities that can arise using Van Cittert techniques. The nonlinear enhancement can provide resolution matched results at a predetermined resolution.

Abstract: Clustering analysis is used to partition data into similarity groups based on mathematical relationships between the measured variables. These relationships (or prototypes) are derived from the specific correlation required between the measured variables (data) and an environmental property of interest. The data points are partitioned into the prototype-driven groups (i.e., clusters) based on error minimization. Once the data is grouped, quantitative predictions and sensitivity analysis of the property of interest can be derived based on the computed prototypes. Additionally, the process inherently minimizes prediction errors due to the rigorous error minimization during data clustering while avoiding overfitting via algorithm parameterization. The application used to demonstrate the power of the method is pressure gradient analysis.

Abstract: Apparatus for calculating service life expectancy of wellbore intervention tools comprising one or more sensors, power means, control means and wireless connectivity means. Also a method of the measuring and calculating the service life expectancy of wellbore intervention tools using this apparatus.

Abstract: To update a model of a subterranean structure, a partial decomposition is computed of an operator that is used to compute a parameterization representing the update of the model. The partial decomposition of the operator is selected from among a partial eigendecomposition of a Fisher information operator, and a singular value decomposition of the operator. A term based on additional information is combined with the partial decomposition of the operator to derive an update of the model.

Abstract: The disclosure is directed to methods and apparatuses for estimating a response relating to a formation by stressing a wall of a borehole during either wireline or while drilling deployment. The response may be estimated by stressing the wall of a borehole formed in the formation; and estimating a response of the borehole wall to the stress. The response may be estimated using a force module configured to induce the stress around borehole and a tool configured to estimate the response of the borehole wall to the stress.

Abstract: A method of processing geological data comprising a plurality of geological surfaces within a geological volume is provided. The method includes the steps of: (i) specifying a well trajectory which extends through the geological volume; (ii) identifying the geological surfaces within the volume which are intersected by the trajectory; (iii) determining, for each intersected surface, the depth, the dip angle and the dip direction of the surface at the point of intersection with the trajectory; and (iv) predicting a well log for the trajectory, the log specifying the depths, dip angles and dip directions of the intersected geological surfaces.

Abstract: Apparatus, computer readable medium, and program code for identifying rock properties in real-time during drilling, are provided. An example of an embodiment of such an apparatus includes a downhole sensor subassembly connected between a drill bit and a drill string, acoustic sensors operably coupled to a downhole processor, a borehole telemetry system, downhole and surface data transmitting interfaces, and a surface computer operably coupled to the downhole data transmitting interface. The downhole processor is adapted to perform operations including receiving raw acoustic sensor data resulting from rotational contact of the drill bit with rock, transforming the raw acoustic sensor data into the frequency domain, filtering the transformed data, and deriving acoustic characteristics from the filtered data. The surface computer is adapted to perform operations including deriving petrophysical properties from the acoustic characteristics directly or by utilizing a petrophysical properties evaluation algorithm.

Abstract: The present disclosure relates to a method to determine a formation property of a subsurface formation. A downhole logging tool having two or more tri-axial antennas is provided and used to obtain azimuthally sensitive data. Borehole correction is performed on the obtained data and a ZD-inversion is performed on the borehole corrected data for all antenna spacing groups. A formation indicator flag is determined and, depending on the determined formation indicator flag, a 1D-axial inversion and/or a 1D-radial inversion is performed over selected zones, or neither is performed. The best ZD-inversion results are selected and the 1D-axial inversion results and/or the 1D-radial inversion results, if any, are combined with the selected best ZD- inversion results to form a composite inversion result. The formation property of the subsurface formation is determined using the composite inversion result.

Abstract: Subsurface reservoir properties are predicted despite limited availability of well log and multiple seismic attribute data. The prediction is achieved by computer modeling with least square regression based on a support vector machine methodology. The computer modeling includes supervised computerized data training, cross-validation and kernel selection and parameter optimization of the support vector machine.

Abstract: This invention relates to petroleum industry, in particularly, to control and monitoring of processes related to reservoir stimulation. A method of real time diagnostic of fracture operations with combination of tube waves and microseismic monitoring, comprising performing a fracture in a wellbore, recording microseismic activity generated during the fracturing operations. Determining of microseismic event locations, generating low frequency pressure waves (tube waves) near the wellbore, recording of tube waves reflections from the fractures in real time and analyzing microseismic event locations and tube waves reflections from the fractures.

Abstract: A method of estimating a parameter of an anomaly in an earth formation includes: disposing a measurement device at at least one measurement location, the measurement device including a frequency standard; estimating a frequency shift of a frequency standard due to a gravitational potential at at least one measurement location; and deriving a relationship between a mass and a depth of a formation anomaly at a distance to the at least one measurement location using the frequency shift.

Abstract: A walkaway VSP survey is carried out using a receiver array. Using a vertical VSP survey and arrival times of surface multiples on the walkaway VSP, vertical interval velocities and the anisotropy parameters ? and ? are estimated. This may then be used to process surface seismic data to do a prestack depth migration of surface seismic data and used for interpretation. For multi-azimuthal walkaway or 3D VSP data, we determine two VTI parameters ? and ? for multi-azimuth vertical planes. Then we determine five anisotropic interval parameters that describe P-wave kinematics for orthorhombic layers. These orthorhombic parameters may then be used to process surface seismic data to give a stacked image in true depth and for the interpretation purposes.

Abstract: An exemplary system for managing the deployment of a seismic data acquisition system uses a module configured to execute a plurality of task in the field by receiving one or more seismic devices. The module may include a power source that provides electrical power to the seismic devices. The module may also include a processor programmed to retrieve data stored in the seismic devices, perform diagnostics, facilitate inventory and logistics control, configure seismic devices and update data or pre-programmed instructions in the seismic device.

Abstract: A method of passive surveying comprises generating one or more detected signals by passively detecting a signal generated within a subsurface earth formation due to a seismoelectric response or an electroseismic response in at least one porous subsurface earth formation containing at least one fluid, and processing the one or more detected signals to determine at least one property of the subsurface earth formation.

Abstract: Systems and methods for positioning horizontal wells within a limited-pre-defined boundary. The systems and methods include an automated process for creating jointed target pairs or horizontal laterals to be utilized for planning horizontal wells in order to position the horizontal laterals within limited pre-defined boundary(ies).

Abstract: The present disclosure relates to methods and apparatuses for evaluating a porous earth formation. The method may include estimating at least one parameter of interest of the earth formation using a displacement velocity of nanoparticles injected into the porous earth formation and exposed to an alternating magnetic field. The method may include using at least one processor to estimate the value of the at least one parameter. The apparatus may include an alternating magnetic field source, nanoparticles responsive to a magnetic field, and a sensor configured to measure the motion of the nanoparticles.

Abstract: Methods and systems for acoustically determining reservoir parameters of subterranean formations. A tool comprising a plurality of acoustic sources and configured for acoustic measurements is deployed within a wellhole. Acquired acoustic data are processed and utilized for deriving key parameters for the formations. The plurality of acoustic sources include a plurality of hammer sources, where at least one of the hammer sources includes an actuator that is adapted to strike a surface to generate acoustic energy.