Abstract: A method and system is provided for managing well assets. The method includes the steps of determining “first tier” statuses corresponding to pre-defined well attributes, mapping the first tier statuses to one or more well performance classifications, determining “second tier” statuses corresponding to the well classifications, and combining the second tier statuses to determine an overall well surveillance status. The method and corresponding system can be used to manage wells by exception, to readily identify “under-performing” wells, and to prioritize actions to be taken by well operators.

Abstract: The invention is a method of constructing a three-dimensional fracture density log of a porous formation traversed by fractures and a borehole. A number N of intersections between the fractures and the borehole is measured over a section of the borehole of length L located at a depth d, from observations of the wall of this section. A conditional probability law of the three-dimensional fracture density is then estimated, knowing the number N of intersections. The value of the three-dimensional fracture density at depth d is determined by calculating the mean of this conditional probability law. Finally, the three-dimensional fracture density log is constructed by repeating the previous stages for different depths. A three-dimensional fracture density uncertainty log can also be associated by calculating quantiles of the conditional probability law.

Abstract: Methods and apparatus for generating a searchable electronic record of a locate operation in which a presence or an absence of at least one underground facility within a dig area may be identified using one or more physical locate marks. Source data representing one or more input images of a geographic area comprising the dig area is received and processed so as to display at least a portion of the input image(s) on a display device. One or more digital representations of the physical locate mark(s) applied to the dig area during the locate operation are added to the displayed input image(s) as “locate mark indicators” so as to generate a marked-up image. Information relating to the marked-up image is electronically transmitted and/or electronically stored so as to generate the searchable electronic record of the locate operation.

Abstract: A multi-station gravity and magnetic survey is carried out in a borehole. The data from the survey are processed to estimate the inclination and azimuth of the borehole. The drill collar relative permeability is estimated, and the estimated drill collar permeability is then used to remove the effects of induced magnetization of the drill collar on the magnetic measurements.

Abstract: The present invention is directed to methods for controlling the operations of a well service rig at a well site by evaluating load sensor data obtained from sensors on or associated with the well service rig. A rig load data chart can be reviewed and an average rig load can be determined for each pull of tubing or rods from a well. The average rig load can be used to calculate and set a rig overload level. If the rig load sensor reads a rig load at or above the rig overload level, the clutch for the hoist can be disengaged and the brake applied to prevent the load from either damaging the rig or breaking off the tubing or rods in the well. In addition, the rig load can be evaluated to determine when the limit the block speed when pulling rods or tubing.

Abstract: Data about operation of a well for extracting a product from the subterranean reservoir and at least one of a characteristic of a subterranean reservoir or operation of a processing and transport system upstream of a point of sale is received. A corrective action can be automatically initiated on at least one of the well or the processing and transport system in response to a difference between the received data and a specified operational objective. An adjustment to a model of the reservoir, the well, and the processing and transporting system can be automatically initiated in response to the received data.

Abstract: To perform inversion based on electromagnetic (EM) data acquired in a subterranean survey, time domain controlled source EM (TD-CSEM) data is acquired by at least one EM receiver in response to EM signals from a controlled EM source. Further data is received, where the further data is selected from among magnetotelluric (MT) data and DC data acquired by the at least one receiver. A probabilistic joint inversion is applied on the TD-CSEM data and the further data to produce a model representing a subterranean structure that is a target of the subterranean survey.

Abstract: An efficient and cost-effective technique is provided to perform modeling of a reservoir in a subterranean structure. A compartment model of fluid compartments in a reservoir is generated, and based on the compartment model and a geomechanical model of the subterranean structure, movement of a ground surface due to volumetric change of the compartments is calculated. Satellite measurements of the ground surface are received over time, where the received satellite measurements of the ground surface over time indicate movement of the ground surface. The movement of the ground surface indicated by the received satellite measurements is compared with the calculated movement, and based on the comparing, one or more properties of the geomechanical model are adjusted.

Abstract: Methods for imaging geological structures include injecting magnetic materials into the geological structures, placing at least one magnetic probe in a proximity to the geological structures, generating a magnetic field in the geological structures and detecting a magnetic signal. The at least one magnetic probe may be on the surface of the geological structures or reside within the geological structures. The methods also include injecting magnetic materials into the geological structures, placing at least one magnetic detector in the geological structures and measuring a resonant frequency in the at least one magnetic detector. Methods for using magnetic materials in dipole-dipole, dipole-loop and loop-loop transmitter-receiver configurations for geological structure electromagnetic imaging techniques are also disclosed.

Abstract: Methods and apparatus for generating a searchable electronic record of a locate operation in which a presence or an absence of at least one underground facility within a dig area may be identified using one or more physical locate marks. Source data representing one or more input images of a geographic area comprising the dig area is received and processed so as to display at least a portion of the input image(s) on a display device. One or more digital representations of the physical locate mark(s) applied to the dig area during the locate operation are added to the displayed input image(s) as “locate mark indicators” so as to generate a marked-up image. Information relating to the marked-up image is electronically transmitted and/or electronically stored so as to generate the searchable electronic record of the locate operation.

Abstract: A methodology that performs downhole fluid analysis of fluid properties of a reservoir and characterizes the reservoir based upon such downhole fluid analysis. The methodology acquires at least one fluid sample at a respective measurement station and performs downhole fluid analysis to measure properties of the fluid sample, including concentration of a plurality of high molecular weight components. For each of a plurality of type classes corresponding to different subsets of a predetermined set of high molecular weight components, a model is used to predict the concentration of the components of the given type class for the plurality of measurement stations. The predicted concentrations of the high molecular weight components for the plurality of type classes are then compared with corresponding concentrations measured by downhole fluid analysis for the plurality of measurement stations to identify the best matching type class.

Abstract: A method for detecting a subterranean anomaly is provided. The method includes receiving signal data derived from a plurality of transmitters and at least one receiver; calculating a relationship for selected combinations of measurements provided by the signal data; estimating weighting factors for each transmitter, for a condition where there is a substantially equivalent potential across each of the transmitters; applying the weighting factors to the data; and identifying the anomaly in weighted data. Apparatus are also provided.

Abstract: In order to increase result accuracy the noise effect during vessel motion is reduced, wherefore direct current pulses are excited the parameters of which are set basing on section conductivity and deposit depth, the electric field is measured simultaneously on pairs of receiving electrodes basing on the spatial averaging of potential of double electric layer that is generated on the boundary of electrode and water during the pulses and pauses between them, and geoelectrical parameters are determined.

Abstract: Embodiments of the present invention provide a machine, program product, and computer-implemented method to select a fit-for-purpose tool for reservoir saturation monitoring. A computer stores a plurality of characteristics for a plurality of well-logging tools, including open hole and closed hole resistivity, pulse-neutron spectral carbon-oxygen, and pulse-neutron capture technologies, as well as a predetermined ranking of tools within a technology. The computer obtains user inputs associated with conditions of a candidate well, e.g., a minimum tubing restriction, whether the wellbore is open or cased, and whether the well is a wet producer. Inputs can also include an objective of the reservoir saturation monitoring, such as, evaluating sweep efficiency or identifying remaining pay for sidetrack or perforation.

Abstract: In some example embodiments, a system includes a drill string having a drill bit. The drill string extends through at least part of a well bore. The system also includes a first vibrational sensor, positioned on the drill bit to measure, at a first location on the drill string, an amplitude of one or more of an axial vibration and a lateral vibration. The system also includes a second vibrational sensor, positioned above the drill bit and on the drill string. The second vibration sensor is to measure, at a second location on the drill string, one or more of an axial vibration and a lateral vibration. The system includes a processor unit to determine a type of vibration based on a comparison of the amplitude at the first location to the amplitude at the second location, wherein the type of vibration is at least one of bit whirl of the drill bit and a while of a bottom hole assembly that is part of the drill string.

Abstract: Three seismic waves are emitted from different emission points situated outside the well that is to be positioned relative to a seismic image. The times of arrival of these seismic waves are measured on a detector placed in the well. The propagation of the seismic waves emitted from the respective emission points is simulated using a speed model that has been used to construct the seismic image. The simulation provides the respective wavefronts presented by each of the waves at the end of a time equal to the time of arrival measured on the detector for this wave. The detector can then be positioned in the envelope area of the wavefronts, adjacent to the intersection of the wavefronts estimated in the seismic volume.

Abstract: A method for correcting a motion related distortion in a sensor measurement comprises establishing a reference position in a borehole. A parameter of interest is measured at a plurality of toolface angles as the tool makes a revolution in the borehole. A distance to a wall of the borehole is measured associated with each parameter of interest measurement. A lateral motion of the tool is measured between each parameter of interest measurement, and a toolface angle of the tool is measured at each parameter of interest measurement. A controller comprising a processor acts according to programmed instructions to calculate a correction to the parameter of interest measurement referenced to the reference position based at least partly on the measured tool motion.

Abstract: Downhole drilling vibration analysis uses acceleration data measured in three orthogonal axes downhole while drilling to determine whether drilling assembly's efficiency has fallen to a point where the assembly needs to be pulled. In real or near real time, a downhole tool calculates impulse in at least one direction using the measured acceleration data over an acquisition period and determines whether the calculated impulse exceeds a predetermined acceleration threshold for the acquisition period. If the impulse exceeds the threshold, the tool pulses the impulse data to the surface where the calculated impulse is correlated to efficiency of the assembly as the drillstring is used to drill in real time. Based on the correlation, operators can determine whether to pull the assembly if excessive impulse occurs continuously over a predetermined penetration depth.

Abstract: Methods and systems for determining reservoir parameters of subterranean formations. A tool is configured or designed for deployment at at least one depth in a borehole traversing a subterranean formation. The tool comprises at least one sensor configured or designed for sensing rotational components of a seismic wavefield deployed in an array comprising at least one sensor configured or designed for sensing translational components of a seismic wavefield. A computer is in communication with the tool and a set of instructions executable by the computer that, when executed, process the seismic measurements and derive parameters relating to the formation based on the seismic measurements.

Abstract: In an exemplary embodiment, a method is disclosed for developing an N-phasic finite element model for performing fully coupled analyses of multi-phase compositional fluid flow and heat flow in nonlinearly deforming porous solid media with time-dependent failure. The method can include formulating a finite element model of the behavior of a coupled solid-fluid formation, having complex geometry and behavior, and applying the model to derive the response of the formation in the form of one or more displacement fields for the solid phases and one or more pressure fields for the fluid phases in a zone of interest in a formation. In an exemplary embodiment, a system is disclosed for estimating the uncertainties in the derived displacement and pressure field solutions for the response of the fully coupled solid-fluid phases.

Abstract: In some aspects of the disclosure, a computer-implemented method performed by one or more processors and configured to determine a pressure of a sample multi-component gas inclusion in a sub-surface formation is disclosed. The computer-implemented method includes determining a set of Raman signatures for a calibration multi-component synthetic gas mixture at a plurality of temperatures, at a plurality of pressures and at a plurality of gas concentration mixing ratios to produce a model of pressure and Raman signatures; determining a second Raman signature of the sample multi-component gas mixture in the inclusion from the sub-surface formation; and determining a pressure of the second multi-component gas mixture based on the determined second Raman signature and the model of pressure and the first set of Raman signatures.

Abstract: To characterize an earth subterranean structure using a measurement assembly including electromagnetic (EM) receivers and one or more EM sources, measured voltage data collected by EM receivers in response to transmission by one or more EM sources is received. Based on a model, predicted EM data is computed. Inversion is iteratively performed according to a function that computes a difference between the measured voltage data and a product of a term containing the predicted EM data and a term containing distortion data that accounts at least for distortion effect by an environment of the measurement assembly. The inversion is iteratively performed to solve for parameters of the model and the distortion data.

Abstract: A system for analyzing an oilfield having at least one wellsite, each at least one wellsite having a wellbore penetrating a subterranean formation for extracting fluid from an underground reservoir therein, that includes a data collection means for obtaining source data having a plurality of data elements of heterogeneous data types, memory for storing the source data, a functional method configured to perform a function on a dataset of a dataset type to obtain a processed dataset, and a client code configured to process the dataset. The client code includes an object instantiation code configured to use a dataset wrapper class to create the dataset with the dataset type from the source data, and a functional method invocation code configured to call the functional method with the dataset.

Abstract: A system and method enable testing of a plurality of well-logging tools on a common, realistic earth model. To enable this testing, a model of a synthetic virtual geologic volume of interest is generated. From the synthetic virtual geologic volume of interest, a plurality of test properties are determined as a function of position within the virtual geologic volume of interest, wherein the test properties are measurable in actual geologic volumes of interest by a well-logging instruments. The individual test properties are then distributed to well-logging instrument developers with the model of the synthetic virtual geologic volume of interest to enable modeling and/or benchmarking of different well-logging instruments on the synthetic virtual geologic volume of interest and the ability to derive the original formation properties regardless of the method used (inversion, analytical solution, etc.).

Abstract: Method and apparatus for transmitting a first data set from a tool to a receiver are provided. The method includes: obtaining a first plurality of measurements using the tool to form a first dataset; saving data from the first plurality of measurements that form the first dataset in non-volatile memory; transmitting first data-groups derived from the first dataset to the receiver, each of the first data-groups comprising different measurements of the formation; and storing in the non-volatile memory a storage position of a last transmitted first data-group. Upon restoration of a loss of communications that prevents transmission of all the first data-groups, determining the storage position of the last transmitted first data-group; and continuing the transmission of the first data-groups from the storage position of the first data-group last transmitted before the loss of communications.

Abstract: A computerized monitoring system and corresponding method of monitoring the status and health of a blowout preventer. The system includes a graphics display at which a graphical user interface (GUI) displays the health of various sealing elements and control systems by way of “traffic light” indicators. The health indicators are evaluated, by the monitoring system, based on a risk profile for each of the indicated elements and control systems. The risk profiles are evaluated based on inputs such as measurement inputs, feedback signals, mechanical positions, diagnostic results, drilling conditions, and other status information of the blowout preventer at a given time and based on levels of redundancy and levels of deviation from normal conditions. The GUI includes recent history of changes in operating condition, and alarm indications such as poor health, along with the times of those events.

Abstract: Methods for determining the locations/heights of fractures in a subterranean formation use a post-fracture log obtained with a compensated neutron or pulsed neutron logging tool. Utilizing predetermined relationships between tool count rates and associated near/far count rate ratios, the methods detect the presence of proppant containing high thermal neutron capture cross-section material, substantially eliminating proppant determination uncertainty resulting from changes in formation hydrogen index. In an interval of a well with given borehole and formation conditions, and not containing proppant, a relationship is developed between detector count rate and near/far ratio. This relationship is used to compute count rate from the ratio in intervals of the well possibly containing proppant and which have similar formation and borehole conditions.

Abstract: An apparatus for estimating a property of a formation penetrated by a borehole, the apparatus having: a first electrode and a second electrode configured to couple to a characteristic impedance of a material disposed in the borehole; a third electrode configured with the first electrode to electrically couple to a characteristic impedance of the formation; a circuit element coupled to the first electrode and to the second electrode and having a characteristic impedance; a first sensing circuit coupled to the circuit element and configured to provide a first signal related to the impedance of the borehole material; and a second sensing circuit coupled to the first electrode and the third electrode and configured to provide a second signal related to the characteristic impedance of the formation; wherein the first signal and the second signal are used to estimate the property. A method is also provided.

Abstract: This application relates to a method and apparatus for the acquisition, processing and inversion of marine control source electro magnetic (CSEM) data. A system provides data acquisition and processing of the responses measured simultaneously by multiple receivers placed in a near zone and partly in the intermediate zone at different distances around the transmitter.

Abstract: One embodiment of the invention involves a model-based method of inverting electromagnetic data associated with a subsurface area that includes developing a three-dimensional electromagnetic property model of the area, and restricting changes that may be made to the model during the electromagnetic data inversion process. Other related embodiments of the inventive method are also described and claimed.

Abstract: A fluids lifting tool and analysis system. The present invention comprises a fluid lifting system for a gas well. The system comprises a lifting tool positioned in the well and a docking station at the well surface. The tool includes a processor, pressure sensors, temperature sensors, an accelerometer, and a proximity sensor. A battery in the tool is adapted to be charged by inductive coupling using coils in the docking station and the tool. The tool is released from the docking station and descends the well. During descent the tool measures elapsed time, velocity of the tool, calculates distance traveled, measures pressure and temperature, determines volumes or oil and water in the well, and senses when the tool reaches the bottom of the well. The FLT chooses to ascend the well when appropriate and transfers measured and calculated data to the docking station.

Abstract: A system and method for optimal placement of a riserless casing in a subsea drilling environment having the steps of: receiving input of pore pressure data for a well site; receiving input of fracture gradient for said well site; receiving input of the anticipated true vertical depth of said well site; integrating pore pressure data, fracture gradient data with said true vertical depth values; computing a pore pressure and fracture gradient verses true vertical depth graph; determining the true vertical depth at which the pore pressure begins to exceed the normal gradient of salt water; and determining the placement of a conductor casing string by corresponding the gradient true vertical depth to the true vertical depth of where the pore pressure beings to exceed the normal gradient of salt water. The method improves upon conventional placement of the riserless casing by optimizing the placement to achieve larger diameters in the wellbore, increased well depth, and mitigation of shallow hazards.

Abstract: A method for modelling a saturation dependant property in a sample by obtaining a spatially resolved measurement of fluid saturation in the sample; determining a measured value of a saturation dependant property from the measurement; fitting a model to the measured value to obtain a model value for the measured value; and optimising the fit of the model to the measured value by minimizing an error between the model and the measured value where the error is a distance between the measured value and the model value.

Abstract: There is provided a transducer assembly for monitoring within a borehole. The transducer assembly is operable to at least one of: (a) generate acoustic radiation when excited with one or more signals; and (b) generate one or more signals when acoustic radiation is received thereat; wherein the transducer assembly includes one or more piezo-electric elements for converting between acoustic radiation and corresponding signals. The assembly includes an interfacing member for acoustically interfacing between the one or more piezo-electric elements and an environment of the borehole for protecting the one or more piezo-electric elements from the environment. The assembly is adapted to at least one of generate acoustic radiation and sense acoustic radiation in a sideways or down-borehole direction.

Abstract: A computer-implemented method of characterizing elastic properties of a subsurface formation at various fluid saturation conditions is disclosed.

Abstract: A method and system for processing three component seismic data includes determining a covariance data matrix from three component seismic data for each of a plurality of time periods to obtain eigenvectors and eigenvalues. One or more seismic attributes are calculated from the eigenvectors and eigenvalues for each of a plurality of time periods. A stability measure is determined from the calculated seismic attribute for each of the plurality of time periods and stored for display.

Abstract: Methods are provided for determining the locations and heights of fractures in a subterranean formation using a neutron-emitting logging tool. Utilizing predetermined relationships (1) between logging tool count rates and associated apparent formation hydrogen index values and (2) between logging tool count rate ratios and associated apparent formation hydrogen index values, the methods detect the presence and heights in the formation of proppant containing high thermal neutron capture cross section material in a manner substantially eliminating proppant determination uncertainty resulting from a prior change in formation hydrogen index values. A second, associated, method employing logging tool count rates and count rate ratios to determine the presence of proppant containing high thermal neutron capture cross section absorbers utilizes a crossplot of count rate versus ratio.

Abstract: A method and apparatus associated with the production of hydrocarbons is disclosed. The method, which relates to modeling and operation of drilling equipment, includes constructing one or more surrogates for at least a portion of a bottom hole assembly (BHA) and calculating performance results from each of the one or more surrogates. The calculated results of the modeling may include one or more vibration performance indices that characterize the BHA vibration performance of the surrogates for operating parameters and boundary conditions, which may be substantially the same as conditions to be used, being used, or previously used in drilling operations. The selected BHA surrogate may then be utilized in a well construction operation and thus associated with the production of hydrocarbons.

Abstract: In some embodiments, apparatus and systems, as well as methods, may operate to launch a set of currents into a corresponding set of existing well casings; monitor, in a well under construction, changes in at least one of a magnetic field or an electric field perturbed by the set of currents after each one of the set is launched; and determine a location of the well under construction in relation to the set of existing well casings. In some embodiments, the activities include inducing current into a drillstring located in a well under construction; monitoring, at a set of existing well casings, changes in at least one of a magnetic field or an electric field perturbed by the current after the current is induced; and determining a location of the well under construction in relation to the set of existing well casings. Additional apparatus, systems, and methods are disclosed.

Abstract: In one embodiment, the invention provides an analytical processing system for enhancing the recovery of heavy oil in an underground, near-surface crude oil extraction environment, comprising: a data collection engine configured for receiving data relating to the underground, near-surface crude oil extraction environment, wherein the data includes in situ microbial species data, oil properties data and in situ nutrient information that are identified as being germane to the underground, near-surface crude oil extraction environment; a data warehouse for storing data collected from the data collection engine; and a data modeling system for analyzing data stored in the data warehouse and facilitating an identity of a preferred microbial species from the underground, near-surface crude oil extraction environment that can transform the heavy oil into a lighter oil.

Abstract: A machine, method and computer-usable medium for modeling an average flow of a substance through a composite material. Such a modeling includes an analytical calculation of an effective tensor Kå suitable for use with a variety of media. The analytical calculation corresponds to an approximation to the tensor K, and follows by first computing the diagonal values, and then identifying symmetries of the heterogeneity distribution. Additional calculations include determining the center of mass of the heterogeneous cell and its angle according to a defined Cartesian system, and utilizing this angle into a rotation formula to compute the off-diagonal values and determining its sign.

Abstract: A system for assessing the health of a mechanism includes a processor for receiving observation data from at least one sensor, the processor including: a detector receptive to the observation data and capable of identifying whether the mechanism is operating in a normal or degraded mode; a diagnoser to identify a type of fault from at least one symptom pattern; and a prognoser capable of calculating a remaining useful life (RUL) of the mechanism, wherein the prognoser includes a population prognoser for calculating the RUL based on a duration of use of the mechanism, a cause prognoser for calculating the RUL based on causal data, and an effect prognoser for calculating the RUL based on effect data generated from the fault. A method and computer program product for assessing the health of a downhole tool is also disclosed.

Abstract: A sensor apparatus comprising a housing, two or three gyroscope units and three accelerometer units. The gyroscope units are oriented orthogonally respective to each other and mounted within the housing. Each gyroscope unit includes a plurality of gyroscopes with input axes parallel to each other. The accelerometer units are oriented orthogonally respective to each other and mounted within the housing. Each accelerometer unit includes a plurality of accelerometers with detection axes parallel to each other.

Abstract: A method for determining electromagnetic induction properties of subsurface rock formations includes determining an eccentering angle of a well logging instrument disposed in a wellbore. The instrument includes at least one triaxial induction transmitter and at least one triaxial induction receiver. The eccentering angle is determined from symmetric cross component measurement differences. The triaxial induction measurements made from the at least one receiver are rotated to an apparent eccentering angle of zero. At least one electromagnetic induction property is determined from the rotated triaxial induction measurements.

Abstract: The invention relates to a method for determining the wear of a force-loaded linkage of an earthwork device, wherein the instantaneous load on the linkage is measured during operation of the earthwork device and used to perform a calculation of the service life.

Abstract: Wellbore data samples related to a subsurface volume of interest are weighted based on wellbore orientation and/or stratal orientation. Declustering weights are determined that account for differences in sampling density caused by wellbore and/or stratal structure orientation. The declustering weights may be implemented to weight samples of parameters taken within wellbores, and/or to update or adjust other weights determined according to other schemes.

Abstract: Plural sensors are deployed into a well, and measurement data regarding at least one property of the well is received from the sensors. Based on the measurement data, a first of the plural sensors that measures the at least one property in a region having an annular fluid flow is identified, and a second of the plural sensors that measures the at least one property in a region outside the region having the annular fluid flow is identified. Based on the identifying, the measurement data from selected one or more of the plural sensors is used to produce a target output.

Abstract: A method for making directional resistivity measurements and forming a directional resistivity image of a subterranean formation includes processing a plurality of directional resistivity measurements and corresponding azimuth angles to calculate a first order harmonic representation at selected azimuth angles. A two dimensional borehole image may be formed by repeating the procedure at multiple measured depths in the borehole.

Abstract: A time measurement device for a geologic downhole measurement tool is provided. The device includes a plurality of oscillators for measuring a time value. At least one of the plurality of oscillators has a first temperature range that is different from a second temperature range of at least another of the plurality of oscillators. A time measurement system and a method for providing a time measurement are also provided.

Abstract: A method and system for determining dynamic permeability of gas hydrate formations including deploying a tool within a wellhole configured for magnetic resonance measurements, determining permeability of a formation at or near zero saturation of the gas hydrate and deriving the relationship between permeability and gas hydrate saturation for the formation.