Abstract: A method, system, and computer-readable medium for providing a visualization of a model. The method includes receiving a grid of the model including cells representing space, time, or both in the model. The method also includes grouping at least some of the cells into first-level gridlets. The method also includes grouping at least some of the first-level gridlets into second-level gridlets. The method further includes determining a first upper limit of elements to send for display, based on a display system capability, and determining that the number of first-level gridlets exceeds the first upper limit, and that the number of second-level gridlets is less than or equal to the first upper limit. In response, the method includes selecting at least some of the second-level gridlets for display and omitting from display at least some of the cells and at least some of the first-level gridlets.

Abstract: A system, computer program product, and computer implemented method are provided for determining an optimal acidizing placement design which would yield a prescribed profile of injection or production rate that accounts for the drawdown from heel to toe and reservoir heterogeneity and thereby improve hydrocarbon recovery.

Abstract: Method of drilling a well, including one method comprising determining a first value indicative of a relative position of a geological bed boundary with respect to a drilling assembly, determining a second value indicative of an optical property of a formation fluid proximate the drilling assembly, and controlling a well trajectory based on the first and second value.

Abstract: Testing scale buildup in a well tool can include pressurizing separate cationic and anionic solutions, then heating the separate solutions, mixing together the solutions, and exposing the well tool to the mixed solutions. A well tool can be constructed by a) determining velocities of flow at a predetermined offset from surfaces of a geometric model representative of the well tool, b) calculating scale buildup on the surfaces based at least in part on the velocities, c) reducing pressure change per unit distance along selected ones of the surfaces having greater than a predetermined level of scale buildup, and d) repeating steps a-c until all scale buildup is no greater than the predetermined level. A method of predicting scale buildup can include inputting a parameter indicative of flow through a well tool to a mathematical model, which determines a rate of scale buildup on a surface of the well tool.

Abstract: A system and method for dynamic selection of reliability by data publishing protocol while publishing data, comprising a constrained gateway device (102) being adapted to publish data by using a data publisher and adapted to send and receive acknowledgment messages, one or more subscriber devices (104) communicatively coupled with the constrained gateway device (102) and subscribed to the server (106) and adapted to send and receive acknowledgment messages, and a server (106) communicatively coupled with the constrained gateway device (102) and the one or more subscriber devices (104) and adapted to exchange the acknowledgement messages between the data publisher on the constrained gateway device (102) and the one or more subscriber devices (104) wherein the data publisher running on the constrained gateway device (102) has multiple reliability levels for publishing data and is adapted to dynamically select the reliability level based on available bandwidth and energy.

Abstract: A method of controlling fluid flow into a heavy oil production pipe is disclosed. The method involves reducing inflow into a production pipe locally from hot spots using inflow control devices comprising a movable body provided within a housing. The movable body is arranged to adjust the flow of fluid through the inflow control devices autonomously by exploiting the Bernoulli principle. Inflow into the production pipe remote from said hot spots may be increased using the inflow control devices to increase inflow locally, and draw down in said production pipe may be increased by using an injector to inject a gaseous medium at or downstream of said inflow control devices.

Abstract: The present invention relates to an apparatus and a method for monitoring a hydrate decomposition area under different drilling and production processes.

Abstract: Apparatus and methods of categorizing a subterranean formation including collecting data related to the formation, performing an algorithm comprising guided Bayesian survey design, identifying data observations to collect, and collecting additional data observations related to the formation. In some embodiments, the performing comprises forming a matrix or loading a matrix or both. Apparatus and methods of categorizing a subterranean formation including collecting data related to the formation, performing an algorithm comprising guided Bayesian survey design, identifying data observations to use, and processing the data observations wherein the observations require less processing time than if no algorithm were performed.

Abstract: Disclosed is a downhole fluid resistivity sensor that includes a ceramic cylinder having a fluid-contacting surface, and at least four metal pins that penetrate a wall of the ceramic cylinder at axially-spaced locations. The pins are bonded to the ceramic to form a pressure seal. The sensor may include a circuit that injects current into a fluid via an outer two of the pins, and measures a resulting voltage via an inner two of the pins. The circuit may also provide an indication of fluid resistivity based at least in part on the resulting voltage. At each of the axially-spaced locations, a set of multiple pins may penetrate the wall to contact the fluid at circumferentially-spaced positions. The fluid-contacting surface may be an inner surface or an outer surface of the ceramic cylinder. A downhole fluid resistivity measurement method is also described.

Abstract: A method for characterizing a property of a subterranean formation including collecting well log and seismic data, inverting the data, processing for upscaled petrophysical parameters, constructing a flow model that generates saturation, pressure and temperature, constructing seismic velocity relationships from the results of the flow model, and constructing a seismic model. Some embodiments may form a full waveform model or a ray tracing model. Some embodiments may generate a velocity profile and/or waveforms using the profile. Some embodiments may use the parameters to form a reservoir model or to recover hydrocarbons from the formations. Some embodiments build a reservoir model of CO2 injection or CO2 presence after injection or for simulating CO2 presence in a subterranean formation. Some embodiments may also quantify CO2 properties in the reservoir or predict CO2 profile evolution over time in the reservoir including spatial distribution.

Abstract: An apparatus and method for facilitating eversion of a flexible liner down a borehole when an artesian head condition is producing a rate of water flow out of the top of the borehole. A bypass pipe channels artesian flow, moving upward in the borehole and/or well casing, past an everting flexible liner to a wellhead fixture. Artesian flow arriving at the wellhead fixture is pumped away to ameliorate resistance to liner eversion otherwise presented by the water flow. A heavy mud may be disposed inside the everting liner further to promote its downward eversion past the artesian flow.

Abstract: A method, apparatus and system for modeling a fault surface in a subsurface region. A direction may be determined in which a first portion of the subsurface region being on one side of the fault surface has moved relative to a second portion of the subsurface region being on the other side of the fault surface. A model of the fault surface may be generated having substantially no protrusions in the determined direction. A visualization of the model of the generated fault surface may be displayed.

Abstract: In some aspects, a first boundary is computed based on microseismic event locations associated with a first stage of a multi-stage injection treatment of a subterranean region. A second boundary is computed based on microseismic event locations associated with a second stage of the multi-stage injection treatment. Based on the first and second boundaries, an overlap between stimulated reservoir volumes (SRVs) associated with the first and second stages is determined.

Abstract: In modeling passage of an elongate well tool through an interval of a well an adaptive machine learning model executed on a computing system receives a first set of inputs representing a plurality of characteristics of the well tool and a second set of inputs representing a plurality of characteristics of the well. The adaptive machine learning model also receives historical data representing a plurality of other well tools passed through a plurality of other wells and a plurality of characteristics of the other well tools and the other wells. The adaptive machine learning model matches the historical data with at least a portion of the first and second sets of inputs, and determines, based on the matching whether the well tool can pass through the interval of the well.

Abstract: System and methods for determining appraisal locations in a reservoir system by generating, selecting and ranking a list of priority appraisal locations based on an adjusted hydrocarbon recovery potential.

Abstract: Systems and methods for determining reserve estimates for a reservoir using a thickness grid multiplied by one or more grids of laterally-varying attributes to produce a unified grid from which the reserve estimates are determined.

Abstract: Systems and methods for dynamically updating compartments representing one or more geological structures by performing one or more dynamic interactions on i) current data; ii) a predefined polygon area-of-interest and/or predefined minimum/maximum depths from volume-of-interest based model sealing; and/or iii) a fluid contact flag and/or a sealing state from a fluid fill analysis.

Abstract: High performance computing (HPC) and grid computing processing for seismic and reservoir simulation are performed without impacting or losing processing time in case of failures. A Data Distribution Service (DDS) standard is implemented in High Performance Computing (HPC) and grid computing platforms, to avoid the shortcomings of current Message Passing Interface (MPI) communication between computing modules, and provide quality of service (QoS) for such applications. QoS properties of the processing can be controlled. A “partitioning” quality of service is provided and the computer can be logically segregated into several “logical partitions” so that a computer can have several publisher nodes, serving several groups of compute nodes, and running different applications independently.

Abstract: A method and apparatus for assessing induced fractures in a subterranean formation including acquiring sonic data before and after a hydraulic fracturing operation, calculating a shear modulus in the borehole cross-sectional plane from Stoneley data, and calculating two shear moduli in two borehole orthogonal axial planes from cross dipole data. A method and apparatus for assessing induced fractures in a subterranean formation including collecting sonic data before and after fracturing the formation, calculating a far-field shear modulus in the borehole cross-sectional plane and a far-field shear moduli in the two orthogonal borehole axial planes, inferring the open or closed status of a fracture, and estimating a radial width or height or both of a vertical fracture.

Abstract: Methods and systems for historical, geological modeling for producing an estimated distribution of hydrocarbons trapped in subsurface clathrates are disclosed. One method includes instantiating a basin model of a geological area of interest, and, for each of a plurality of predetermined geological times up to a geologic present day: determining one or more changes to the basin model, calculating, at each of a plurality of locations within the basin model, a temperature and a pressure, determining an existence and a location of a clathrate stability zone based on the calculated temperatures and pressures, and estimating one or more clathrate concentrations and hydrocarbon volumes in the clathrate stability zone.

Abstract: A method for assessing an inflow performance relationship for a horizontal well in heterogeneous solution gas drives reservoirs. A commercial simulator Eclipse is utilized to develop IPRs for horizontal wells producing oil from solution gas drive reservoirs. Firstly, a simulation model is developed where a base case is considered with typical rock, fluid and reservoir properties using a black oil model. Dimensionless IPR curves are generated by obtaining a set of points relating to flowing bottom-hole pressures to oil production rates. The effects of several reservoir and fluid properties such as bubblepoint pressure, oil gravity, residual oil saturation, critical gas saturation, initial water saturation, porosity and absolute permeabilities on the calculated curves are investigated. A new single empirical IPR model is obtained for horizontal wells producing oil from heterogeneous solution gas drive reservoirs suitable for systems with different reservoir permeability.

Abstract: Automated methods of creating a predictive test load, using clustering to create the predictive test load from production data, for testing in a production environment. Client requests to a production system are captured and processed into production request data. The production request data undergoes a clustering analysis to determine cluster definitions. In some embodiments, the production request data is turned into vectors and the vectors undergo the clustering analysis instead of the production data. A specification may be received that specifies modifications to be made to the production data. The production request data may be processed using the cluster definitions and the specified modifications to create a predictive test load. In some embodiments, the predictive test load is played to a production system to simulate a predictive load according to a test plan. The test plan may specify the rate at which the test load is replayed.

Abstract: Systems and methods for structured and unstructured reservoir simulation using parallel processing on GPU clusters to balance the computational load.

Abstract: The invention is a method of developing a petroleum reservoir employing a technique for selection of the position of the wells to be drilled. A production indicator map is utilized comprising a set of cells each associated with a production indicator defining impact on fluid production of addition of a well in this cell. The production indicator map is constructed by selecting cells from among the set of cells of the map; determining production indicators in the selected cells; and interpolating the production indicators on the set of cells of the map, by an interpolation model accounting for a distance between the cell to be interpolated and the closest well to the cell to be interpolated. The position of the well to be drilled is defined by the cell where the production indicator is a maximum.

Abstract: A method and system for modeling a subsurface structure at a time when the structure was originally formed. A first model having non-planar horizons representing a current subsurface structure may be used to calculate a vector field based on the non-planar geometry of the horizons of the model. The vector field may be non-uniform or uniform. Geographic coordinates of the first model may be transformed to paleo-geographic coordinates of a model representing the subsurface structure in the past, where the non-planar horizons in the first model are transformed to planar horizons in the second model. A set of points describing one or more fractures in the subsurface structure may be used to calculate a tuning parameter to correct a first set of paleo-geographic coordinates. A second set of coordinates representing an improved prediction at a time period when the subsurface structure was originally formed may be generated.

Abstract: Systems, methods, and software can be used to simulate a fracture treatment. In some aspects, physically separate rock blocks of a subterranean zone are modeled by separate block models. The block model for each physically separate rock block represents intra-block mechanics of the rock block, for example, as a group of discrete block elements. Interactions between adjacent pairs of the rock blocks are modeled by separate joint models. The joint model for each adjacent pair of rock blocks represents inter-block mechanics between the adjacent rock blocks, for example, as pre-defined joints. The block models and joint models are used to simulate an injection treatment of the subterranean zone.

Abstract: A method of estimating flow properties of an earth formation includes: selecting a grid block representing a region of the earth formation, the region including at least one of an area and a volume of the earth formation, the grid block including a plurality of grid cells and having an orientation defined by grid axes; and calculating a fluid flow model of the region. Calculating the model includes: estimating a principal flow direction for each grid cell; adjusting the orientation of the grid block based on the principal flow direction; and calculating fluid flow parameters in each grid cell to generate the fluid flow model.

Abstract: In some aspects, a one-dimensional flow model is generated. The one-dimensional flow model can represent flow of a first fluid and a second fluid in a flow path in a well system environment. The one-dimensional flow model comprises an effective diffusion coefficient model for a composite fluid volume comprising the first and second fluids. The effective diffusion coefficient model calculates an effective diffusion coefficient for the composite fluid volume based on a difference between the respective densities and viscosities of the first fluid and the second fluid.

Abstract: A population comparison system, method and a computer program product therefor. A stored list of population members, e.g., hydrocarbon reservoirs, characteristics and analogous members is partitioned into lists for each member. A weighting system automatically uses the partitions to determine a weight set (w*) for population member characteristic and a similarity function. The weighting system may include an objective model that iteratively, blindly identifies analogous members for each population member until the identified analogous members match the listed analogous members. An analogous member selector uses the weights set (w*) and similarity function to automatically select analogous listed members for each new population member.

Abstract: A method is disclosed for determining wettability in a subsurface reservoir. Embodiments of the method utilize image analysis techniques for determining wettability indicator values. Wettability indicator values may be determined based on a hydrocarbon wet fraction and a water wet fraction of pore linings, which may both be determined by image analysis of pore walls lined with hydrocarbons using images of sections obtained from core samples. Further details and advantages of various embodiments of the method are described in more detail herein.

Abstract: A method, apparatus and computer-readable medium for determining a lifespan of an electronic component in a downhole environment is disclosed. A first wear-out model is created that is related to a selected electronic component. A physical condition of the selected electronic component is examined at a selected examination time. The physical condition is generally due to the downhole environment in which the electronic component is disposed. A second wear-out model for the selected electronic component is created from the first wear-out model and the examined physical condition of the selected electronic component.

Abstract: One or more computer-readable media include computer-executable instructions to instruct a computing system to iteratively solve a system of equations that model a wellbore and fracture network in a reservoir where the system of equations includes equations for multiphase flow in a porous medium, equations for multiphase flow between a fracture and a wellbore, and equations for multiphase flow between a formation of a reservoir and a fracture. Various other apparatuses, systems, methods, etc., are also disclosed.

Abstract: A method can include identifying a discrete natural fracture in a three-dimensional environment that includes a reservoir modeled by a three-dimensional grid model, representing the discrete natural fracture via a multisegment model in a two-dimensional region within the three-dimensional grid model, defining at least one connection for fluid communication between the multisegment model and the three-dimensional grid model, defining boundary conditions for the multisegment model, and solving the multisegment model subject to the at least one connection and the boundary conditions to provide values for fluid flow in the two-dimensional region. Various other apparatuses, systems, methods, etc., are also disclosed.

Abstract: In solving linear systems of billions of equations resulting from reservoir simulator pressure equations for giant reservoirs organized into fine-grid models, a multi-level methodology acquires a fast and coarser grid solution to be used as a more accurate initial estimate for the fine grid problem. Solver iterations performed on the coarser grid in reduced processing time generate a better initial estimate, resulting in fewer of the more expensive iterations at the fine-grid level.

Abstract: Systems, methods, and software can be used to calculate fracture stratigraphy of a subterranean zone. In some aspects, microseismic event data associated with a fracture treatment of a subterranean zone are received, and the subterranean zone includes multiple subsurface layers. A filter is used to select a subset of the microseismic event data corresponding to fractures in a particular subsurface layer. Fracture stratigraphy is calculated for the particular subsurface layer from fracture planes associated with the selected subset of the microseismic event data.

Abstract: The present disclosure relates to modeling the flow of fracturing fluid in a subterranean formation. Fluid flow within the reservoir media in a subterranean formation is modeled by a reservoir block flow model. Fluid flow within a fracture network in the reservoir is modeled by a fracture network flow model. Fluid flow between the fracture network and the reservoir media is modeled by an interface flow model. Output data are generated based on coupling the fracture network flow model, the reservoir block flow model, and the interface flow model. The output data represent characteristics of fracturing fluid leak-off from the fracture network into the reservoir media.

Abstract: Various embodiments include apparatus and methods that use hand mobile communications device with respect to a drilling operation at a drilling site. Data with respect to one or more sensors downhole at a drilling site can be wirelessly received in the hand mobile communications device. Representations of the received data can be displayed on a graphical user interface screen of the hand mobile communications device. The representations can include displaying the data in a graphical representation, a numerical representation, or a graphical and numerical representation on the graphical user interface screen. Additional apparatus, systems, and methods are disclosed.

Abstract: A system and method, implemented on a computer, for determining the uncertainty of soft-data debiasing of property distributions of spatially correlated reservoir data are provided. The method includes inputting, into the computer, soft-data at a plurality of spatial locations on a grid and hard-data at a plurality of location along well paths that intersect the grid. Each location of the hard-data is collocated with soft-data values of one or more types.

Abstract: A testing system for performing image based direct numerical simulation to characterize petrophysical properties of a rock sample under the simulated deformation condition, for example as representative of subsurface conditions. A digital image volume corresponding to x-ray tomographic images of a rock sample is segmented into its significant elastic phases, such as pore space, clay fraction, grain contacts and mineral type, and overlaid with an unstructured finite element mesh. A simulated deformation is applied to the segmented image volume, and the resulting deformed unstructured mesh is numerically analyzed, for example by way of direct numerical simulation, to determine the desired petrophysical properties.

Abstract: Autonomous non-destructive inspection equipment provides automatic and/or continuous inspection and evaluation of a material under inspection. The inspection equipment comprises at least one detection sensor and at least one detection sensor interface for a computer. The signals are communicated from the sensor to the computer. The signals are then conditioned and evaluated according to knowledge already inputted into the computer. The computer iterations are processed until an acceptable conclusion is made regarding the type of imperfection that is detected.

Abstract: A method for determining reservoir architecture using modeling of a non-equilibrium distribution of at least one analyte in reservoir fluids. The analyte(s) of the analysis preferably has (have) significant compositional variation in the reservoir. For example, the analyte can be a later charging single gas component (such as methane, carbon dioxide, or hydrogen sulfide) in a multi-component fluid system. In this case, the model can assume that the components of the early charge are in a stationary state or in equilibrium, whereas the later charge is in a state of non-equilibrium. The non-equilibrium distribution of the analyte(s) derived from the model is compared to the distribution of the analyte(s) derived from downhole or laboratory fluid analysis of reservoir fluid, and the architecture of the reservoir is determined based upon such comparison.

Abstract: A method for inhibiting an explosive atmosphere in a wellbore drilling system, including a riser (12) connected to a wellbore above a top thereof wherein the riser has a fluid outlet (17) below a surface of a body of water in which the wellbore is drilled, and wherein the fluid outlet is connected to a subsea pump to return drilling fluid to a drilling platform on the water surface and wherein a space in the riser (12) above the drilling fluid level filled with air includes pumping drilling fluid into a drill string (15) extending from the drilling platform into the wellbore. Fluid (27) is introduced proximate an upper end of the riser (12). A rate of introducing the fluid (27) is selected to inhibit an explosive atmosphere in the space in the riser above the drilling fluid level. The subsea pump to remove fluid from the riser outlet is operated at a rate selected to maintain the fluid level or to maintain a selected wellbore pressure.

Abstract: An apparatus and method for estimating reservoir connectivity using gravity estimates at a fluid contact for each of two or more boreholes. The method may include identifying fluid contacts in the boreholes. The method may include additional gravity estimates at and/or between a well head and the fluid contact of each borehole. The method may include gravity estimates along a surface between well heads of the boreholes. The method may include estimating true vertical depth for the boreholes. The apparatus may include at least one gravimeter and a processor configured to estimate reservoir connectivity using estimates from the gravimeter.

Abstract: This invention relates to enhanced oil recovery methods to improve hydrocarbon reservoir production. An enhanced oil recovery screening model has been developed which consists of a set of correlations to estimate the oil recovery from miscible and immiscible gas/solvent injection (CO2, N2, and hydrocarbons), polymer flood, surfactant polymer flood, alkaline-polymer flood and alkaline surfactant-polymer flood.

Abstract: A system, method and computer program product for generating probabilistic models of a subsurface region of the earth of interest. The system, method can be implemented efficiently to enable real-time imaging of a sub-surface structure. The system, method can provide users with the ability to assess where their subsurface images are reliable and where they are not in order to assist in the selection of low-risk, high-reward sights indicated as having oil potential for drilling. The system, method allows users to estimate a degree of uncertainty to be expected when drilling in a specific location. The knowledge of this uncertainly can be used to guide drilling in real-time to reduce the time to oil (and thereby the cost of drilling), increase the efficiency of drill maintenance and reduce the risk associated with incorrectly identifying the depth at which pressure might spike.

Abstract: Systems, methods, and instructions encoded in a computer-readable medium can perform operations related to simulating subterranean fracture propagation. A subterranean formation model representing rock blocks of a subterranean formation is received. The subterranean formation model is used to predict a response of each rock block to one or more forces acting on the rock block during an injection treatment for the subterranean formation. The predicted responses of the rock blocks may include, for example, a fracture, a rotation, a displacement, a dilation of an existing fracture, and/or another type of response. In some implementations, an injection treatment may be designed for a subterranean formation based on the predicted response of the rock blocks.

Abstract: Modeling hydrocarbon flow, from layered shale formations. At least some of the illustrative embodiments are methods including: modeling movement of hydrocarbons through kerogen-related porosity, the movement through a first model volume; estimating a first permeability of a kerogen-rich layer of a layered shale formation based on the modeling; and modeling hydrocarbon production from the layered shale formation. The modeling hydrocarbon production may include: utilizing the first permeability for the kerogen-rich layer of the layered shale formation; and utilizing a second permeability for a kerogen-poor layer of the layered shale formation, the second permeability different than the first permeability. In various cases the modeling of hydrocarbon production is with respect to a second model volume greater than the first model volume.

Abstract: According to the invention, in order to initialize the use of a multipoint geostatistical technique (MPS), the method takes information, which was collected in wells drilled in the area of the subsoil to be modeled, into account. Particularly, the method takes inter-well connectivity data into account, which indicate one or more groups of cells of a reservoir grid that are located along a plurality of wells and between which hydrodynamic communications have been observed. For each of said groups, compatible thumbnail images are searched for in a training image used in the MPS technique. Said thumbnail images have, in the training image, facies that enable the flows between the cells of the group. The thumbnail images are applied onto the reservoir grid in order to initialize MPS simulation while ensuring that the inter-well connectivity constraints will be respected.

Abstract: Reservoir simulation is performed for giant reservoir models in a parallel computing platform composed of a number of processor nodes. Automatic precautionary checkpoints are made at regular time intervals when computational time exceeds a preset value. The simulator receives and reacts to signals from a real time monitoring interface tool which monitors the health of the system. Checkpoints are also made done if a system problem which may cause a simulation job to fail is projected. The simulation job is subsequently restarted to continue simulation from the last checkpoint. The monitoring and automatic recovery are done automatically without need for user intervention.

Abstract: Modeling hydrocarbon flow from kerogens in a hydrocarbon bearing formation. At least some of the illustrative embodiments are methods including modeling flow of hydrocarbons through a hydrocarbon bearing formation by: obtaining an indication of kerogen-wet porosity of kerogen within a portion of the formation; obtaining an indication of water-wet porosity within the portion of the formation; modeling hydrocarbon movement through the kerogen-wet porosity; and modeling hydrocarbon movement through the water-wet porosity.