Abstract: A method may include collecting measurement data using a first operational sensor and a second operational sensor of a downhole tool, standardizing optical responses of each operational sensor to a master sensor in a tool parameter space to obtain a standardized master sensor response, transforming the standardized master sensor response to a synthetic parameter space response of the master sensor, applying a fluid model with the synthetic parameter space response of the master sensor to predict a fluid characteristic, comparing a first prediction obtained with the fluid model from the first operational sensor with a second prediction obtained with the fluid model from the second operational sensor, determining a fluid characteristic from the first prediction and the second prediction, and optimizing a well testing and sampling operation according to the fluid characteristic.

Abstract: A method and system provide automated mapping of fluid distributions in an oil field reservoir. The processes include receiving initial fluid and pressure characteristics of well-pairs in the field. Measurements from sensors detect the amount of fluid injection versus fluid produced for the well-pair during a timestep. The remaining fluid volume for the well-pair may be determined. In an exemplary embodiment, a grid map of well-pairs in the oil field are automatically generated which shows in real-time the remaining volume of fluid for each well-pair in the map. A user may thus manage the production from the oil field with increased efficiency based on the improved accuracy of the mapped data.

Abstract: A method includes: performing a machine learning process using information for enhanced oil recovery (EOR) materials to be used for an EOR process on a defined oil reservoir; determining EOR materials suitable for a condition of the oil reservoir; listing the EOR materials; and outputting an indication of the EOR materials. The materials comprise a first complex fluid to be introduced into the oil reservoir. Determining the EOR materials suitable for the condition is based on similarities between a first set of vector values for the first complex fluid, a second set of vector values for a second complex fluid already in the oil reservoir, and geological data, each of the vector values of the first set being defined by parameters of the first complex fluid and each of the vector values of the second set being defined by parameters of the second complex fluid and the geological data.

Abstract: A downhole tool includes a membrane to separate water from a formation fluid and a meter that operates as a densitometer and a Coriolis effect flowmeter.

Abstract: There is described an apparatus for monitoring at least a portion of a wellbore, the apparatus comprising a body including at least an anchoring means for releasably positioning the apparatus with respect to a tubular in the wellbore. The apparatus comprises detecting means for detecting at least one parameter of a substance in the portion, and in that the apparatus comprises transceiver means configured to at least transmit data related to the parameter.

Abstract: A method, apparatus, and program product for determining a formation pressure for a reservoir. Measurement data for a pretest of a formation of the reservoir is received. The measurement data is analyzed to determine a last-read event and a corresponding last-read pressure. Derivative data for flow regime identification is determined based at least in part on the measurement data. The derivative data is analyzed to determine a pressure derivative response, and a formation pressure is determined based at least in part on the last-read event, the last-read pressure, and the pressure derivative response.

Abstract: Systems and methods for a hybrid approach to assisted history matching in large reservoirs based on a reservoir model built using connectivity between each production well and each corresponding injection well, aquifer or gas cap.

Abstract: A method for estimating one or more properties as a function of depth of an earth formation penetrated by a borehole includes: receiving nuclear magnetic resonance (NMR) logging data having NMR echo trains as a function of depth in the borehole; receiving non-NMR logging data having non-NMR measurement values for one or more types of non-NMR measurements as a function of depth in the borehole; generating an evolution matrix (E) representing a mathematical relationship between the one or more properties in property matrix (P) to be estimated and the NMR logging data and non-NMR logging data matrix (M); generating a matrix equation of the form M=E·P; and inverting the matrix equation to estimate the one or more properties as a function of depth.

Abstract: Estimates are formed of reservoir pressure between the wells for subsurface hydrocarbon producing reservoir. The estimation is based on field data and physical laws governing the hydrocarbon flow in porous media. Information from 3-dimensional fine geological and numerical reservoir simulation models, statistical interpolation between the wells, and static bottom-hole pressure (SBHP) surveys (measurement) at wells are used to more rapidly determine 2-dimensional isobaric reservoir pressure maps for times of interest during the reservoir simulation.

Abstract: Methods, systems, and computer program products for range-based sensitivity analysis in hydrocarbon reservoir modeling are disclosed. A computer-implemented method may include receiving a first numeric range defined as a minimum value and a maximum value for a first input parameter of a computational model, computing a different computational model result for each of a plurality of values in the first numeric range by using each of the values as the first input parameter in different respective computational model calculations, and displaying results of the computational model calculations.

Abstract: Two control strategies may be implemented to optimize mud circulation in a drilling mud circulation system. In a networked control strategy, the mud circulation system does not involve any centralized controller yet all the local controllers can exchange information in real-time via a central data storage. The master-slave control strategy involves a centralized optimizer, and the subsystems are treated as slave systems and are driven by a visual master control system.

Abstract: A method of analyzing fines migration in a multiphase flow in a sediment layer using X-ray computed tomography (CT) image includes, preparing an X-ray CT image analysis sample; analyzing an X-ray CT image during a depressurization process; calibrating and calculating a fines content; and estimating a fines migration analysis result.

Abstract: A method using a fast algorithm automated analysis of time series sensor data that can find an optimal clustering value k for k-means analysis by using statistical analysis of the results of clustering for a stated maximal upper value of k.

Abstract: An estimated value for invasion depth of an invasion zone in a subsurface measurement zone is calculated in a one-dimensional optimization procedure based on multi-array laterolog measurement data. A one-dimensional optimization problem is defined as having the invasion depth as a sole variable measurement zone parameter. The one-dimensional optimization problem is then solved by automated, iterative modification of the invasion depth value. The one-dimensional optimization problem can be a function to minimize a misfit error between (a) multi-array measurement values for resistivity of the subsurface measurement zone, and (b) predicted measurement values calculated in accordance with a simulated measurement zone model based at least in part on the invasion depth.

Abstract: Saturation-height functions in oil and gas reservoirs are determined using methods that include quantifying the microporosity of the subterranean formation; determining the distribution of facies and microporosity as a function of depth; and calculating the saturation-height function for a given formation.

Abstract: A method for estimating a fluid pressure required to stimulate a subsurface formation includes using seismic signals detected by a plurality of seismic sensors disposed proximate the subsurface formation. Spatial positions and times of origin (“hypocenters”) of each of a plurality of microseismic events induced by pumping fluid into the subsurface formation are estimated. Magnitudes and directions of principal stresses are estimated from the hypocenters and from amplitude and phase of the detected seismic signals for each of the microseismic events. Shear and normal stresses of induced fractures are from the estimated principal stresses. A fluid pressure required to cause formation failure on each fracture is estimated using the estimated shear and normal stresses.

Abstract: A system and method utilizing a modified Euler Characteristic to numerically quantify and rank connectivity of a geobody within a reservoir model based upon a range of petrophysical properties.

Abstract: Disclosed herein are embodiments of systems, methods, and computer program products for assessing the data-quality of the calculated reservoir-rock resistivity Rsd in laminar formations. For instance, in one embodiment, a computer-implemented method for assessing the data-quality of the calculated reservoir-rock resistivity Rsd in laminar formations comprises the steps of receiving multi-component induction (MCI) data and other sensor logs data associated with a laminar formation; determining a set of calculated reservoir-rock resistivity Rsd using at least one of the multi-component induction (MCI) data and other sensor logs data; and performing data quality assessments of the set of calculated reservoir-rock resistivity Rsd.

Abstract: An analytical solution is obtained for a pseudo-steady state production from a vertically fractured well with finite or infinite fracture conductivity. The analytical solution may be used to compute a pseudo-steady state constant for the reservoir. Subsequently, performance parameters relating to the reservoir may be derived from the pseudo-steady state constant. For example, parameters such as production decline rate, total hydrocarbon reserves, and economically recoverable reserves for the reservoir may be computed. The disclosed analytical solution, instead of a conventional numerical simulation, can significantly speed up analysis and improve the accuracy of the calculation of these parameters.

Abstract: Distributing petrofacies using analytical modeling. At least some of the illustrative embodiments are methods including: creating, by a computer system, a geocellular model of an underground formation, the creating by: reading a first value of a first rock property associated with a first well log; associating the first value of the first rock property with a first cell of a plurality of cell of the geocellular model; assigning a value of the first rock property to each cell of the plurality of cells based on the first value and a datum of information, the datum of information distinct from the first value.

Abstract: A method for graphically representing a subterranean space from the perspective of a point within the subterranean space, in some embodiments, comprises: obtaining data associated with the subterranean space, said data corresponding to a plurality of coordinates in a first coordinate system; associating the data for each of said plurality of coordinates with one or more corresponding coordinates in a second coordinate system; generating a different model of the subterranean space based on the data and said associations; and displaying the different model on a display, wherein the different model represents the subterranean space from the perspective of a point within the subterranean space.

Abstract: Techniques for allocating hydrocarbon production include receiving a selection of a particular area identification (ID) of a plurality of area IDs stored on the server; determining based on the selected particular area ID, a plurality of hydrocarbon production values that include periodic area-level hydrocarbon production values associated with the particular area ID and a plurality of wells associated with the particular area ID; determining a decline curve model for the area-level hydrocarbon production values associated with the particular area ID; modeling the aggregated periodic well-level hydrocarbon production values with the determined decline curve model; and determining allocated well-level hydrocarbon production values based at least in part on the selected decline curve model to display at a client device.

Abstract: Method for exploiting a fluid within an underground formation comprising a layer traversed by a fracture network and a well. From property measurements relative to the layer, the fracture network is characterized by statistical parameters and a discrete fracture network model is constructed. For each well, three simplification zones surrounding the well are defined. From the statistical parameters, an equivalent permeability tensor and a parameter characterizing the orientation and the vertical continuity of the fractures are determined for each zone. For each zone, a simplification of the discrete fracture network model is determined as a function of the zone, the equivalent permeability tensor and the value of the parameter. An optimum exploitation scheme is defined for the formation fluid from the simplified fracture network model and a flow simulator.

Abstract: Automated systems and methods provide a systematic determination of suitable placements for well production zones that comply with specified placement constraints while accounting for information in the geocellular model. One computer-based well placement method embodiment includes: creating a three-dimensional geocellular model of a subsurface region including a reservoir; determining a map-view layout of well candidate zones that satisfies a set of layout parameters; deriving a three-dimensional arrangement of well production zones by testing each well candidate zone's potential vertical positions against a set of arrangement parameters; and storing the three-dimensional arrangement of well production zones on a non-transient information storage medium for use in evaluating production from the reservoir.

Abstract: Some examples of determining wellbore leak crossflow rate between formations in an injection well are described. During normal operation of an injection well, multiple bottomhole pressures are determined based on multiple surface injection pressures. An Inflow Performance Relationship (IPR) for the injection well is determined based on the multiple bottomhole pressures and the multiple injection flow rates. After shut-in responsive to a subsurface leak, the shut-in injection well is modeled as a producing well having the IPR determined during normal operation of the injection well. A crossflow rate in the injection well at a location of the subsurface leak in the injection well is determined based on the IPR of the modeled producing well.

Abstract: An apparatus for producing gas for use in medical applications. The apparatus includes a compressed gas unit having at least one container of compressed gas and a solenoid valve. An adjustable pressure regulator communicably connected to the gas container, separate and distinct from the solenoid valve, is adjusted to control the pressure of the gas provided from the container to the solenoid valve. An electrical power source is connected to the solenoid valve. A pressure activated electronic switch connected to the power source is responsive to a selected amount of voluntary fingertip, pressure for opening the solenoid valve to transmit the gas therethrough to a conduit, which further transmits the gas to a destination for use or storage.

Abstract: Systems and methods are directed to oil and gas management. In example implementations, data relating to oil and gas management is aggregated and placed in a cube along several cube dimensions, which can include scalar, temporal and spatial dimensions. The dimensions can be structured as a hierarchy, such that output can be generated as a roll up or roll down along the hierarchy.

Abstract: The present invention relates to a method of modelling channel ways. In particular, this method comprises steps for determining a set of stochastic channelway trajectories as a function of a local directional component and of a trigonometric component and for providing the determined trajectory of the channel way which complies with a certain number of constraints. A point of one of the trajectories belongs to an entry constraint. Finally, the set of trajectory constraints is complied with by the determined set of trajectories.

Abstract: Formation testing which may involve circulating mud in a pipe string from a mud pit through a port in the pipe string to a downhole diverter sub, wherein the pipe string is suspended in a wellbore extending into a subterranean formation, operating a downhole pump to pump formation fluid from the formation, wherein the formation fluid comprises gas, and mixing the pumped formation fluid with circulated mud such that a proportion of the pumped formation gas in the circulated mud is maintained below a threshold value.

Abstract: Systems and methods for correlating gas condensates and wet gases in unconventional shale plays based on an equation of state using a condensate gas-ratio, a separator pressure and a separator temperature.

Abstract: Seismic data from seismic exploration surveys are mapped into a hypercube of bins or voxels in a four-dimensional space (X, Y, Offset, and Azimuth) according to Common Mid-Point (or CMP) between source and receivers. The mapped data from individual voxels or bins is then analyzed by multimodal statistics. Robust estimates of first break picks are obtained from the analysis. The first break picks are then used to as seed inputs for autopicking iteration, which proceeds to convergence. Estimates of confidence levels in the data are provided for re-picking to reduce computer processing time in successive autopicking iterations. Analysis is provided of different seismic attributes such as azimuthal velocity variations indicative of anisotropy, positioning errors of sources/receivers, geometry errors, and three dimensional distribution of inversion residuals. Analysis is also performed of standard deviation of the travel time data useful for estimating data errors in the inversion covariance matrix.

Abstract: Machine, computer readable medium, program code, and computer-implemented methods for performing a reservoir simulation with well completion and reservoir grid data quality assurance, are provided. An exemplary embodiment can include a data quality analyzing machine having memory containing data quality analyzing instructions configured to simulate a reservoir model with automated well completion and reservoir grid data quality assurance.

Abstract: Disclosed are systems and methods for predicting a stabilized pressure in a wellbore of a well after an undesired influx of formation fluids, i.e., a kick, into the wellbore in a real-time drilling operation. Following the kick, the well is shut in. Signals representing pressure data associated with the subterranean casing, drill pipe, wellhead, and/or the bottomhole assembly and associated time data are received in a processor. A regression analysis is performed using the pressure data and associated time data in the processor and solved for a predicted stabilized pressure associated with the subterranean casing, the drill pipe, the wellhead, and/or the bottomhole assembly respectively. The regression analysis is performed around a variant of the radial diffusivity equation describing the rate-pressure relationship for flow of a production fluid. The predicted stabilized pressure is communicated to a user.

Abstract: Analyzing wells of mature field. At least some of the illustrative embodiments are methods including: gathering data about a group of wells; determining a condition of each well; creating an initial prioritization; creating a secondary prioritization based on at least one criteria provided by the client and the initial prioritization; analyzing at least some of the wells selected based on priority of each well in the secondary prioritization; interfacing with a service providing entity; providing to the client a first recommendation regarding corrective action, the first recommendation without regard to the service providing entity's availability to perform services; providing to the client a second recommendation regarding corrective action, the second recommendation taking into account the service providing entity's availability of crews and equipment; and performing at least one corrective action on at least one well, the performing based from the first or second recommendations.

Abstract: A blowout preventer (BOP) safety system for testing the integrity of safety valves at the sea floor is disclosed. The system includes a BOP stack including a BOP, the BOP comprising a BOP shear ram and a first hydraulic circuit, the first hydraulic circuit in fluid communication with the BOP shear ram and having an open side and a close side. The system further includes a manifold, wherein the manifold is disposed proximate to and in fluid communication with a dump valve, a first sensor, and a supply valve and a first safety valve disposed between and in fluid communication with the manifold and the BOP on the close side, wherein the dump valve is operable to allow flow from the BOP to the manifold through the safety valve, and wherein the first sensor is operable to detect the flow from the BOP to the manifold.

Abstract: Machine, computer readable medium, program code, and computer-implemented methods for performing a reservoir simulation with well completion and reservoir grid data quality assurance, are provided. An exemplary embodiment can include a data quality analyzing machine having memory containing data quality analyzing instructions configured to simulate a reservoir model with automated well completion and reservoir grid data quality assurance.

Abstract: A method for measuring load performance of a positive displacement motor (PDM) test coupon. The test coupon includes a partial length of a PDM stage and is received inside a sealable test chamber. In some embodiments, the test coupon may be cut from a failed PDM stage. The test chamber is filled with test fluid. In some embodiments, the test fluid may be drilling fluid sampled from a live well. Rotation of the rotor on the test coupon actuates rotation of the stator. A braking torque is applied to the stator rotation, enabling evaluation of, for example, fatigue load performance of test coupon. Additional embodiments comprise the rotor axis and the stator axis being offset in order to simulate rotor/stator eccentricity in a full size PDM stage.

Abstract: A method and computer-readable medium for establishing an uncertainty for obtained values of a one-dimensional logging parameter mapped to a three-dimensional volume is disclosed. A relation is formed between the obtained values of the logging parameter and a volumetric parameter of the three-dimensional volume. A set of representative data points is obtained that relates the obtained values of the logging parameter to the volumetric parameter by binning the obtained values. A plurality of regression curves are then determined, wherein each regression curve is obtained by adding a random error to the set of representative data points to obtain a set of randomized data points and performing a regression analysis using the set of randomized data points. The plurality of regression curves are used to establish the uncertainty for the values of the logging parameter in the three-dimensional volume.

Abstract: Well production rate, injection rate and pressure data are measured in an existing reservoir using in situ real time measurement gauges. Production and injection rates are entered as input to a history match model in a data processing system. Measures of projected reservoir pressure with time are generated by running the updated history match model using a reservoir simulator. Actual reservoir data values obtained at a given date or time slice from reservoir production are compared with projected data obtained from the reservoir simulator for that same date or time slice. At each time slice, the real-time pressure values measured at the wellbore are converted into reservoir pressures through a well model. The real time reservoir pressure values and the projected reservoir pressure are then used to interpolate the reservoir pressure array over the entire three dimensions using a geostatistical modeling process.

Abstract: A method of modeling the spatial variation in wind resource at a prospective wind farm site. The method involves a simplified analysis of the Navier-Stokes equation and utilizes data from all of the met sites simultaneously to develop site-calibrated models. The model coefficients, mUW and mDW, describe the sensitivity of the wind speed to changes in the upwind and downwind terrain exposure and are defined for downhill and uphill flow. The coefficients are a function of terrain complexity and, since terrain complexity can change across an area, the estimates are performed in a stepwise fashion where a path of nodes with a gradual change in complexity is found between each pair of sites. Also, coefficients are defined for each wind direction sector and estimates are performed on a sectorwise basis. The site-calibrated models are created by cross-predicting between each pair of met sites and, through a self-learning technique, the model coefficients that yield the minimum met cross-prediction error are found.

Abstract: Selecting hydrocarbon wells for well testing. The selecting may include identifying hydrocarbon wells whose last well test took place prior to a predetermined date; identifying hydrocarbon wells with a parameter that exceeds a predetermined threshold; and selecting a predetermined number of hydrocarbon wells from the wells identified.

Abstract: Embodiments disclosed herein relate to a method for analyzing a fixed cutter drill bit, said method including selecting a cutter; selecting an earth formation; simulating drilling performance of the fixed cutter bit having at least once cutter thereon; performing finite element analysis using outputs from the simulating; and outputting stress on the at least one cutter.

Abstract: The present disclosure relates to a visual interface for identifying layers within a subterranean formation. One example method includes identifying one or more sets of data associated with a subterranean formation; computing, by operation of one or more processors, a working line based on the one or more sets of data, the working line representing a numerical average of the one or more sets of data; presenting the working line and the one or more sets of data in a common plot in a visual interface; identifying one or more layer boundaries for one or more of the layers of the subterranean formation; and generating layer data based on the one or more identified layer boundaries and the working line.

Abstract: An apparatus and method for NMR analysis of a plurality of core samples includes a core holder (11) that holds a core sample under pressurized conditions. A radio frequency coil (51) disposed about the core holder (11) generates a pulsed-mode magnetic field component over a sample volume occupied by the core sample. A support structure is removably secured to the respective core holder. A permanent magnet (65A, 65B) has an open configuration such that it is removably disposed into a position within the support structure about the radio frequency coil and the core holder. The open configuration allows the same permanent magnet to be used for NMR analysis of a plurality of core samples without the need for depressurizing the respective core holder and disassembling the core holder and corresponding load frame for each core sample. It also allows multiple core samples to be prepared for NMR analysis while separated from the NMR measurement apparatus.

Abstract: A method of measuring parameters of a formation along multiple axes is disclosed. A formation tester tool is introduced into a wellbore. The formation tester tool includes a first probe oriented at an angle from a second probe about an axis of the formation tester tool. The first and second probes are positioned against a surface of the wellbore. Fluid is injected via at least one of the first and second probes. Pressure parameters corresponding to the fluid injected into the formation are monitored. Formation stresses about the formation fractures along multiple axes are determined based, at least in part, on the pressure parameters.

Abstract: In an example diagnostic fracture injection test (DFIT), or a “minifrac,” a fracturing fluid is pumped at a relatively constant rate and high pressure to achieve a fracture pressure of a subterranean formation. Sometime after achieving formation fracture pressure, the pump is shut off and the well is shut in, such that the pressure within the sealed portion of the well equilibrates with the pressure of the subterranean formation. As the pressure declines, the pressure of the injection fluid is monitored. This collected pressure data is then used to determine information regarding the permeability of the subterranean formation. In some implementations, a model for before closure analysis (BCA) can be used to estimate the permeability of a formation based on before closure pressure data (i.e., data collected before the fracture closure pressure is reached) based on a solution to the rigorous flow equation of fracturing fluid, which is leaking off into the formation during fracture closure.

Abstract: Methods and apparatus for operating a downhole tool within a wellbore adjacent a subterranean formation to pump contaminated fluid from the formation into the downhole tool while measuring first and second fluid properties of the contaminated fluid. The contaminated fluid comprises native fluid from the formation and a contaminant. The downhole tool is in communication with surface equipment located at surface. The downhole tool and/or surface equipment is operated to estimate a formation volume factor of the contaminated fluid based on at least one of the first and second fluid properties of the contaminated fluid. A linear relationship is then estimated between the first fluid property and a function that relates the first fluid property to the second fluid property and the estimated formation volume factor of the contaminated fluid. A fluid property of the contaminant is then estimated based on the estimated linear relationship.

Abstract: A method for determining when a plunger reaches the bottom of an oil or gas well equipped with a plunger lift system. More particularly, the method identifies a surface pressure associated with the plunger reaching the bottom.

Abstract: A method for modeling a dynamic system (e.g., geological system) comprises: constructing an input parameter space for a model of the geological system, the input parameter space including more than three dimensions, and the model associated with response data, representing the input parameter space visually with three or fewer dimensions, reducing the input parameter space by conditioning the parameter space using at least a subset of the response data, and updating the representation of the input parameter space to visually represent the reduction of the parameter space.

Abstract: Disclosed are an apparatus and a method of measuring porosity and permeability of a carbon dioxide underground storage medium. Both of the porosity and the permeability are measured in the state that the confining pressure is applied once. The variation characteristic in the porosity and the permeability of the core sample according to the salt precipitation occurring when supercritical carbon dioxide is injected is continuously measured. The apparatus includes a holder receiving a core sample, a pressure pump applying a confining pressure to the core sample, a gas chamber storing gas and supplying supply the stored gas to the core sample, first to third pressure gauges measuring an internal pressure of the gas chamber and front and rear portions of the holder, and a gas flow meter measuring a flow rate of gas.