СИСТЕМА, МАШИНОЧИТАЕМЫЙ НОСИТЕЛЬ И СПОСОБ КОМПЬЮТЕРНОЙ ОБРАБОТКИ ДАННЫХ CCE-ТЕСТА ПЛАСТОВОЙ НЕФТИ ТИПА "BLACK OIL"

Изобретение относится исследованию и компьютерной обработке данных пластовых углеводородных флюидов с ярко выраженными признаками образования паровой фазы. Предложен способ компьютерной обработки данных ССЕ-теста пластовой нефти типа «black oil», который включает следующие шаги: получают данные, включающие по крайней мере массивы однофазной и двухфазной областей экспериментальных PV-изотерм; производят оценку корректности данных и сглаживание экспериментальных данных путем построения аппроксимирующей данные полиномиальной кривой, причем оценка корректности данных включает по крайней мере следующие проверки: отсутствия экстремумов и перегибов на графике аппроксимирующей функции, невыпуклости графика аппроксимирующей функции, превышения коэффициентом достоверности аппроксимации заданного критического значения непревышения максимальных расхождений между расчетными значениями и значениями, определенными экспериментально, допустимых величин; в случае некорректности данных осуществляют исключение ...

СПОСОБ И УСТРОЙСТВО ДЛЯ ОЦЕНКИ СКОРОСТИ ВРАЩЕНИЯ И КРУТЯЩЕГО МОМЕНТА НА ЗАБОЕ СКВАЖИНЫ ДЛЯ СКВАЖИННОГО БУРОВОГО ОБОРУДОВАНИЯ ПРИ БУРЕНИИ, СКВАЖИННОЕ ОБОРУДОВАНИЕ И КОМПЬЮТЕРНЫЙ ПРОГРАММНЫЙ ПРОДУКТ

Предложены способ и устройство, скважинное буровое оборудование и машиночитаемый носитель для оценки по меньшей мере одного из скорости вращения на забое скважины и крутящего момента на забое скважины для скважинного бурового оборудования при бурении скважины в породной формации. Скважинное оборудование содержит вращательную приводную систему, бурильную колонну, компоновку низа бурильной колонны, содержащую буровое долото, верхний конец, соединенный с вращательной приводной системой, и регулятор скорости, выполненный с возможностью управления скоростью вращения верхнего привода путем управления его крутящим моментом. Предложенный способ осуществляют на компьютере на основании вычислительной модели на основе двухпортовой матрицы перехода в спектральной области скважинного бурового оборудования. При бурении получают (54) значения скорости вращения и крутящего момента верхнего привода и вычисляют (55) скорость вращения и крутящий момент на забое скважины путем уменьшения ширины спектральной ...

СПОСОБ ВЫПОЛНЕНИЯ РАЗВЕДКИ

Изобретение относится к способам вычисления вероятного положения структур в земной коре. Предложен способ вычисления вероятных положений структур в некотором районе земной коры, в котором определяют указанный район в земной коре, создают первую структурную модель указанного района по сейсмическим данным с неопределенностями и корреляциями. Создают вторую структурную модель указанного района по результатам измерений в стволе скважины с неопределенностями и корреляциями. Создают третью структурную модель указанного района по результатам измерений в некотором объеме вокруг указанного ствола скважины, отсчитываемых от ствола скважины с неопределенностями и корреляциями. Определяют ограничивающие уравнения для указанных первой, второй и третьей структурных моделей и, используя указанные ограничивающие уравнения, вычисляют вероятные положения структур в указанном районе и вероятные неопределенности и корреляции, связанные с указанными положениями. Технический результат – повышение информативности ...

Predicting downhole mechanical cleaning efficiency in wellbore walls during wellbore fluids displacements

Predicting the efficiency of downhole mechanical removal of one or more accreted materials from one or more wellbore walls may prevent the unnecessary consumption of resources in a wellbore fluids displacement operation. A method and system for removing accreted materials in a wellbore is provided, wherein the efficiency of mechanical removal of accreted materials may be characterized based, at least in part, on a comparison between one or more actual shear stresses exerted by a wellbore servicing fluid at one or more depths of the wellbore and one or more required shear stresses to remove the accreted materials from the depth. The one or more required shear stresses may be determined using one or more of one or more known properties of the one or more accreted materials, one or more rheology models, one or more hydraulic parameters, one or more wellbore hydraulic models, and one or more downhole conditions. To account for one or more effects of eccentricity in the wellbore, the one or ...

Self-adapting digital twins

A system and method can be used for implementing self-adapting digital twins. The system may include operations for estimate a state matrix characterizing behavior of a hydrocarbon recovery process implemented by a hydrocarbon recovery tool. Observed values of one or more sensors for at least one process parameter may be obtained from sensors deployed throughout the drilling environment. These sensors may be physical sensors acquiring information about physical changes within the drilling environment; and processes monitoring output of system functions and/or other processes. A data assimilation tool may be applied to the estimated state matrix and the observed values to produce an updated state matrix. The updated state matrix may be used as the previous state matrix in a subsequent time step, thus implementing a self-adapting digital twin model.

Automated pump-down

An apparatus and method for performing automated pump-down operations. An apparatus may include a control system configured to be communicatively connected with a fluid pump disposed at a wellsite surface and with a conveyance device disposed at the wellsite surface. The control system may be operable to cause the conveyance device to unwind a conveyance line connected with a tool string disposed within a wellbore, and cause the fluid pump to pump a fluid into the wellbore such that the fluid moves the tool string along the wellbore while the conveyance device unwinds the conveyance line.

Systems and methods for integrated and comprehensive hydraulic, thermal and mechanical tubular design analysis for complex well trajectories

Systems, methods, and computer-readable media for an integrated and comprehensive hydraulic, environmental, and mechanical tubular design analysis workflow and simulator for complex well trajectories. An example method can include obtaining data defining a configuration of a wellbore having a complex well trajectory, one or more operations to be performed at the wellbore, and one or more loads associated with the wellbore; calculating environmental conditions associated with a set of wellbore components along the complex well trajectory based on the data defining the configuration of the wellbore, the one or more operations, and the one or more loads; calculating stress conditions associated with the set of wellbore components based on the environmental conditions and the data defining the configuration of the wellbore, the one or more operations, and the one or more loads; and presenting the environmental conditions and the stress conditions via a graphical user interface.

Learning based Bayesian optimization for optimizing controllable drilling parameters

A method for optimizing real time drilling with learning uses a multi-layer Deep Neural Network (DNN) built from input drilling data. A plurality of drilling parameter features is extracted using the DNN. A linear regression model is built based on the extracted plurality of drilling parameter features. The linear regression model is applied to predict one or more drilling parameters.

Method of planning and/or performing an offshore well operation

Casing wear calculation

A method for calculating wellbore casing wear is provided that includes determining a wellbore boundary for an open hole wellbore segment, calculating a casing shape within the open hole wellbore segment based on one or more casing attributes, determining whether or not the casing shape exceeds the wellbore boundary, calculating casing wear based on the boundary of the open hole wellbore segment if the casing shape is determined to exceed the wellbore boundary, otherwise calculating the casing wear parameter based on the casing shape if the casing shape is determined not to exceed the wellbore boundary, and storing the casing wear parameter on a computer readable medium.

Methods of and apparatuses for transforming acoustic log signals

Automated optimization of real-time data frequency for modeling drilling operations

Optimized methodology for automatic history matching of a petroleum reservoir model with ensemble kalman filter

Reservoir history matching

A method for unbiased estimation of individual metal thickness of a plurality of casing strings

Systems and methods for integrated and comprehensive hydraulic, thermal and mechanical tubular design analysis for complex well trajectories

Estimation of fracture properties based on borehole fluid data, acoustic shear wave imaging and well bore imaging

Drilling monitoring and control systems

Method and system for constructing statistical emulators for reservoir simulation models with uncertain inputs

Self-adapting digital twins

System and method for probability-based determination of stratigraphic anomalies in a subsurface

Raw data corresponding to geochemical elemental analysis of rock samples are associated with the concentration of elements in the rock samples. P-values are calculated with a pairwise sum rank test between populations of data corresponding to a given well complex. Fingerprint elements from the rock samples are selected based on the p-values having a value above a given limit. Raw concentrations corresponding to the fingerprint elements are converted to isometric log-ratios ilr data. Mixture discriminant analysis is applied to the ilr data, using ilr sub-populations to calculate posterior probabilities of the rock samples. The stratigraphic anomaly is identified based on the posterior probabilities. In an aspect, the rock samples are assigned to corresponding stratigraphic units based on a priori data, the raw data are transformed to a centred log-ratios dataset, and a number of ilr sub-populations within each stratigraphic unit are determined from the ilr data using a Bayesian information ...

Identifying types of contaminations of drilling fluids for a drilling operation

Mud-gas analysis for mature reservoirs

Conveyance modeling

A conveyance model 710 for predicting an output 730 in response to an input, wherein: the input comprises one or more of a wireline input 722, a toolstring input 724, a well input 726, and/or a conveyance input 728; and the output comprises one or more of a surface weight versus depth output, a cable head tension versus depth output, and a jarring effect output.

Method to engineer dependability into abandonment/kick-off plugs

A system and method comprising utilizing numerical analysis to determine the dependability of plug formulations and locations in wells. The plugs are typically used for abandonment or kick-off purposes. The system and method rely on defining initial physical and material properties, generating a geometric model, and applying loads and boundary conditions to the model. The numerical analysis is preformed to determine stress or deformation for the components of the well, thus providing a basis for selecting a suitable well plug formulation and location.

Reservoir history matching

Systems and methods for reservoir history matching based on closed loop interaction between a geomodel and a reservoir model.

Method and apparatus for production logging tool (PLT) results interpretation

Methods and systems are presented in this disclosure for evaluation of formation properties (e.g., permeability, saturation) based on interpretation of data obtained by production logging tools (PLTs). Based on the PLT data, a production rate for a component (e.g., production fluid) produced by a wellbore can be determined, and a distribution of a property of the component can be initialized along a length of the wellbore. A simulated production rate for the component can be calculated, based on the distribution of the property using a simulator for the wellbore. The distribution of the property can be iteratively adjusted based on the production rate and the simulated production rate, until convergence of the distribution for two consecutive iterations is achieved. A reservoir formation model used for operating the wellbore can be updated based on the adjusted distribution of the property of the component.

SYSTEM AND METHOD FOR TREATMENT OPTIMIZATION

A sequence of stimuli produced by an electric frac pump can be generated by a treatment optimization system. Well environment responses to the sequence of stimuli may be measured by sensors and respective sensor data may be received. The sensor data may be used to select a representative system model which can then be used to control the electric frac pump. The representative system model may be used to achieve well stage objectives such as particular cluster efficiencies, complexity factors, or proximity indices.

TECHNIQUES FOR EXTRACTION OF VECTORIZED CONTENT OF AN OIL AND GAS PLAY WITHIN AN UNSTRUCTURED FILE

... 20 Abstract A method includes retrieving an unstructured document and defining an area of interest of the unstructured document that visually represents geological formation information. The method also includes extracting a set of vectorized polygons from the area of interest. Additionally, the method includes assigning properties from the unstructured document to each of the vectorized polygons in the set of vectorized polygons. Further, the method includes assigning a coordinate reference frame to the set of vectorized polygons and generating a user-interactive document from the set of vectorized polygons. Date RecuelDate Received 2020-12-14 ...

SIMULATING FLUID PRODUCTION USING A RESERVOIR MODEL AND A TUBING MODEL

Fluid production can be simulated using a reservoir model and a tubing model. For example, pressure data and saturation data can be received from a reservoir model simulating a hydrocarbon reservoir in a subterranean formation. A tubing model can be generated by performing nodal analysis using the pressure data and the saturation data. A well-test result can be received that indicates an amount of fluid produced by the wellbore at a particular time. A tuned tubing model can be generated by adjusting the tubing model such that a tubing-model estimate of the amount of fluid produced by the wellbore at the particular time matches the well-test result. An estimated amount of fluid produced by the wellbore can then be determined using the tuned tubing model. The estimated amount of fluid produced by the wellbore may be used for production allocation or controlling a well tool.

DRILLING SYSTEMS AND METHODS

A drilling system (10) comprises a plurality of machines (22) with machine sensors (23), process sensors (24), a drilling electronic control unit (12) including a data processing apparatus (14) and a memory (15) including a process model (15a) and a reservoir model (15b). The drilling electronic control unit (12) is configured to receive process sensor values (26); receive an operating state (25); and calculate and display differences (200, 200') between process sensor values and limits (28_0, 28_1) of a process range (28), and differences (210, 210') between operating state (25) and limits (27_0, 27_1) of a machine's operating range (26), on a drilling screen (28).

EXTRACTING HYDROCARBONS FROM A SUBTERRANEAN HYDROCARBON RESERVOIR BASED ON AN ARTIFICIAL LIFT PLAN

Examples of techniques for extracting hydrocarbons from a subterranean hydrocarbon reservoir based on an artificial lift plan are disclosed. In one example implementation according to aspects of the present disclosure, a method includes performing, by a processing device, an evaluation of an artificial lift approach that can be operated at a well having a subterranean hydrocarbon reservoir, the evaluation being based at least in part on a static factor associated with operating the artifical lift approach in the well and a dynamic factor associated with operating the artifical lift approach at a operating condition. The method further includes generating, by the processing device, an artificial lift plan based at least in part on the evaluation. The method further includes extracting the hydrocarbons from the subterranean hydrocarbon reservoir based on the artificial lift plan by operating, at the well, the artifical lift approach.

A METHOD OF AND A DEVICE FOR ESTIMATING DOWN HOLE SPEED AND DOWN HOLE TORQUE OF BOREHOLE DRILLING EQUIPMENT WHILE DRILLING, BOREHOLE EQUIPMENT AND A COMPUTER PROGRAM PRODUCT

A method of and a device, borehole drilling equipment and a computer program product for estimating at least one of down hole speed and down hole torque of borehole drilling equipment while drilling a borehole in an earth formation. The borehole equipment comprising a rotational drive system, a drill string, a bottom hole assembly comprising a drill bit, a top end coupled to the rotational drive system, and a speed controller arranged for controlling rotational top end drive speed by commanding a top end drive torque. The method being performed in a computer based on a two-port spectral domain transfer matrix computational model of the borehole drilling equipment (50). While drilling, rotational top end drive speed and top end drive torque are obtained (54) and down hole speed and down hole torque of the borehole drilling equipment are calculated (55) by reducing spectral bandwidth of and applying a time delay term to the calculations (53) enabling a causal time domain solution.

COMPLEXITY INDEX OPTIMIZING JOB DESIGN

Selecting a fracing-plan-to-apply to optimize a complexity index includes identifying a set of controllable input variables that defines a fracing plan. Initial values for the set of controllable input variables are defined. The initial values of the set of controllable input variables are processed to produce an initial stimulated geometry. A complexity estimator is applied to the initial stimulated geometry to produce an initial complexity index, which is evaluated to identify at least one variation from the initial values, which is processed to produce a variation stimulated geometry for each of the at least one variation from the initial values. The complexity estimator is applied to the at least one variation stimulated geometry to produce a variation complexity index for each of the at least one variation from the initial values. The fracing-plan-to-apply is selected from among the initial values and the at least one variation from the initial values.

MODELLING OF OIL AND GAS NETWORKS

An oil and gas network comprises multiple branched flow paths, such as in multi-zonal wells and/or multibranched wells and/or networks including multiple wells, and multiple control points (20, 32) at different branches, wherein the multiple control points (20, 32) may include multiple valves (20) and/or pumps (32) for controlling the flow rate through respective flow paths of the multiple branched flow network. The network is modelled to model the variation of one or more flow parameter(s) (12) in one or more flow path(s) of the network. A method for this modelling includes: generating a long-term model (8) using a first set of data (10, 12) relating to measurements of the flow parameter(s) and the status of the control points (20, 32) over a first period of time, wherein the long-term model (8) describes the relationship between flow rates, the status (10) of control points (20, 32), and measured flow parameters (12) including pressure and/or temperature; generating a short-term model ...

INVERSION PROCESSING OF WELL LOG DATA

The disclosed embodiments include devices and methods to perform inversion processing of well log data. In one embodiment, a method to perform inversion processing of well log data includes obtaining an initial model of an earth formation based on a plurality of modeling parameters that includes formation parameters of the earth formation and calibration factors associated with orientations of antennas of a logging tool utilized to measure raw measurements of the earth formation. The method also includes performing a forward modeling of the modeling parameters to obtain a modeling response, and performing a joint cost function of the first modeling response and raw measurements obtained by the logging tool. The method further includes readjusting the initial model if a result of the joint cost function is not below a threshold, and providing the modeling response if the result of the joint cost function is below the threshold.

TOOL-SPECIFIC STEERING OPTIMIZATION TO HIT A TARGET

One or more wellbore trajectories and respective control inputs are determined which meet a wellbore trajectory model, a constraint, and a wellbore length. A wellbore trajectory and respective control input from the one or more wellbore trajectories and respective control inputs are then identified which minimize a cost function associated with the performance objective. The control input associated with this wellbore trajectory are output to a drilling system for drilling a wellbore.

METHOD AND APPARATUS FOR PRODUCTION LOGGING TOOL (PLT) RESULTS INTERPRETATION

Methods and systems are presented in this disclosure for evaluation of formation properties (e.g., permeability, saturation) based on interpretation of data obtained by production logging tools (PLTs). Based on the PLT data, a production rate for a component (e.g., production fluid) produced by a wellbore can be determined, and a distribution of a property of the component can be initialized along a length of the wellbore. A simulated production rate for the component can be calculated, based on the distribution of the property using a simulator for the wellbore. The distribution of the property can be iteratively adjusted based on the production rate and the simulated production rate, until convergence of the distribution for two consecutive iterations is achieved. A reservoir formation model used for operating the wellbore can be updated based on the adjusted distribution of the property of the component.

METHOD OF FORMING DIRECTIONALLY CONTROLLED WORMHOLES IN A SUBTERRANEAN FORMATION

A method for forming extended wormholes in a subsurface formation comprising locating producer wells, injection wells, and guard wells in a field; determining a flux rate for a formation-dissolving fluid such as an acid, the flux rate being dependent upon different variables including the composition of the rock matrix making up the subsurface formation and the type of acid selected; injecting a guard fluid into the subsurface formation, through at least one guard well to form designed pressure boundaries and injecting the acid into the formation at a rate to reach the determined flux rate and thereby forming an extended network of wormholes through the subsurface formation in a defined direction or plane, with or without guard wells.

CUTTING STRUCTURE DESIGN WITH SECONDARY CUTTER METHODOLOGY

A drill bit for subterranean drilling operations is disclosed. The drill bit comprises a drill bit body with one or more blades. The drill bit further comprises a plurality of primary cutters, each primary cutter located on at least one blade, and a plurality of secondary cutters, each secondary cutter located on at least one blade other than the blade on which the primary cutters are located.

SYSTEM AND METHOD FOR SIMULATION OF GAS DESORPTION IN A RESERVOIR USING A MULTI-POROSITY APPROACH

A hydrocarbon shale reservoir simulation system and method represented by a model having at least four different types of porosity nodes is described. The method includes the computer-implemented steps of characterizing porosity nodes within the model as one of natural fracture pore systems, matrix pore systems, induced fracture pore systems or vug pore systems. Following characterization, transfer terms between nodes are identified. Transfer terms may include transfer terms between vug nodes, matrix nodes, natural fracture nodes and induced fracture nodes. Once transfer terms have been assigned, the linear system for the model can be solved utilizing a linear solver. The method further includes the steps of utilizing the characterized pore nodes to define one or more subgrids that represent a zone within the reservoir, wherein the zone includes at least one node of each porosity type; and wherein the linear solver is applied by subgrid or associated subgrids.

Multi-point geostatistical prestack inversion method based on renewal probability ratio constant theory

A multi-point geostatistical prestack inversion method based on a renewal probability ratio constant theory, comprising the following steps: sorting information, work area gridding and distributing well data, assigning an initial attribute value to a simulation work area, selecting a data template with an appropriate size, inversion and judging iteration termination; the method overcomes the defects that in the prior art, oil and gas exploration and development are more and more difficult, exploration degree is higher and higher, new oil and gas reservoirs are more and more difficult to find, reservoir parameters are inaccurate, and exploration uncertainty is increased, and the method has the advantages that prior information is obtained through a multi-point geostatistics method and then screening is carried out through a minimum objective function such that the complexity of seismic inversion is reduced.

CALIBRATING A WELLBORE TRAJECTORY MODEL FOR USE IN DIRECTIONALLY DRILLING A WELLBORE IN A GEOLOGIC FORMATION

One or more sensors are positioned downhole in a wellbore of a geological formation. One or more survey directional measurements associated with the wellbore are performed and one or more continuous directional measurements associated with the wellbore are performed. A wellbore trajectory model projects a trajectory of the wellbore to respective measured depths where at least one of the one or more survey directional measurements and one or more continuous directional measurements were performed to predict one or more directional measurements of the wellbore at the respective measured depths. One or more errors are determined based on the predicted one or more directional measurements, the one or more survey directional measurements, and the one or more continuous directional measurements. The wellbore trajectory model is calibrated based on the one or more errors.

Interpretation Of Pumping Pressure Behavior And Diagnostic For Well Perforation Efficiency During Pumping Operations

A method may comprise plotting treatment data to form a plot of the treatment data, fitting a function to the plot of the treatment data, determining an intercept of the function, calculating one or more coefficients, plotting the one or more coefficients on a histogram, and identifying one or more active flowpath elements on the histogram. A system may comprise a fluid handling system and an information handling system. The fluid handling system may comprise a fluid supply vessel, wherein the fluid supply vessel is disposed on a surface; pumping equipment, wherein the pumping equipment it attached to the fluid supply vessel and disposed on the surface; wellbore supply conduit, wherein the wellbore supply conduit is attached to the pumping equipment and disposed in a formation; and a plurality of flowpath elements, wherein the flowpath elements fluidly couple the wellbore supply conduit to the formation.

DETERMINATION OF VIRTUAL PROCESS PARAMETERS

A method can include generating a first predictive model associated with a first well of a plurality of wells in a cluster, the first well configured to produce a first fluid output and a second well of the plurality of wells configured to produce a second fluid output, the first and the second fluid outputs flow to a cluster manifold via a system of pipelines in the cluster. The method includes receiving data characterizing one or more pressure measurements in the cluster and indicative of one or more pressure values associated with the first fluid output, and the second fluid output. The method can further include recalibrating the first predictive model based on the one or more of the pressure measurements and historical data associated with the first well. Related apparatus, systems, articles, and techniques are also described.

Method and Device for Hole Cleaning and Drilling Hydraulic Design

A system includes a processor. The processor estimates a pattern of a flow of a mixture of drilling fluid and cuttings in an annulus of a wellbore. The flow is estimated as a stationary bed flow, a dispersed flow, or a transitional flow relative to the stationary bed and dispersed flows. The processor estimates parameters based on the estimated pattern of the flow, and determines a plurality of dimensionless parameters including a first dimensionless parameter corresponding to an effect of turbulence on the flow and a second dimensionless parameter corresponding to an effect of gravity on the flow, based on the estimated parameters. The processor characterizes the pattern of the flow as the stationary bed flow, the dispersed flow, or the transitional flow, based on the dimensionless parameters, and models the flow based on the estimated pattern if it is determined that the characterized pattern matches the estimated pattern.

Resolution preserving methodology to generate continuous log scale reservoir permeability profile from petrographic thin section images

Embodiments of the present disclosure aim to provide advanced log scale permeability estimation systems and methods. In an embodiment, a computer system is provided and configured to perform petrographic thin section image permeability analysis and then generate log scale permeability estimations for a well using machine learning methods and techniques. In an embodiment, the advanced log scale permeability estimation systems and methods are configured with a computer system or a micro-computer system, that can be configured with a computer circuit board comprising a processor, memory, networking capability, and software. In another embodiment the log scale permeability estimations for a well are input into a reservoir simulation model to determine hydrocarbon resources and to make portfolio predictions for a well.

Method For Selection Of Cement Composition For Wells Experiencing Cyclic Loads

Methods of the present disclosure relate to quantitative assessments of the risk of damage to cement sheaths due to cyclic loads. A method comprises selecting cement compositions; performing wellbore integrity analyses using models for cement sheaths, each cement sheath comprising a selected cement composition; and determining a number of cycles to failure for each cement sheath.

METHOD AND SYSTEM FOR DETERMINING HOLE CLEANING EFFICIENCY BASED ON WELLBORE SEGMENT LENGTHS

A method may include obtaining, in real-time with a drilling operation, density data regarding a drilling fluid circulating in a wellbore. The method may further include determining mud velocity data of the drilling fluid in the wellbore based on flow rate data and a borehole area of the wellbore. The method may further include determining a cuttings weight of the drilling fluid in the wellbore based on the density data. The cuttings weight and the mud velocity data may correspond to a respective segment length among various segment lengths of the wellbore. The method may further include determining, based on the cuttings weight, the mud velocity data, and a hole cleaning model, various hole cleaning efficiency (HCE) values for the segment lengths of the wellbore. The method may further include determining whether an HCE value among the HCE values fails to satisfy a predetermined criterion.

Interpretation of pumping pressure behavior and diagnostic for well perforation efficiency during pumping operations

A method may comprise plotting treatment data to form a plot of the treatment data, fitting a function to the plot of the treatment data, determining an intercept of the function, calculating one or more coefficients, plotting the one or more coefficients on a histogram, and identifying one or more active flowpath elements on the histogram. A system may comprise a fluid handling system and an information handling system. The fluid handling system may comprise a fluid supply vessel, wherein the fluid supply vessel is disposed on a surface; pumping equipment, wherein the pumping equipment it attached to the fluid supply vessel and disposed on the surface; wellbore supply conduit, wherein the wellbore supply conduit is attached to the pumping equipment and disposed in a formation; and a plurality of flowpath elements, wherein the flowpath elements fluidly couple the wellbore supply conduit to the formation.

Multiscale modeling workflow of advanced waterflooding

Disclosed are methods, systems, and computer-readable medium to perform operations including performing, using a nanoscale model, a simulation of fluid-fluid and fluid-rock interactions in the subterranean formation. The operations also include upscaling first results of the simulation of fluid-fluid and fluid-rock interactions to a microscale level. The operations further include performing, using a microscale model and the upscaled first results, a simulation of fluid flow inside rocks of the subterranean formation. Additionally, the operations include upscaling second results of the simulation of fluid flow inside rocks to a macroscale level. Further, the operations include performing, using a core-scale model and the upscaled second results, a simulation of fluid flow across the subterranean formation.

SYSTEM AND METHOD FOR SUPERVISED LEARNING OF PERMEABILITY OF EARTH FORMATIONS

Embodiments herein include a method for characterizing a rock formation sample. The method for characterizing a rock formation sample includes obtaining a plurality of data sets characterizing the rock formation sample. The method further includes training a neural network to generate a computational model. Moreover, the method additionally includes using the plurality of data sets as input to the computational model, wherein the computational model may be implemented by a processor that derives an estimate of permeability of the rock formation sample.

In-situ evaluation of gauges

Methods for evaluating sensor data to predict when the sensor should be recalibrated are described. The methods include a model that utilizes current wellbore data as input for the recalibration prediction.

Corrosion prediction for integrity assessment of metal tubular structures

A method for assessing an integrity of metal tubular structures may comprise receiving one or more inputs, applying an algorithm to automatically select an appropriate model for a given corrosion scenario, applying a combined model including semi-empirical and multiphase flow corrosion characteristics to the one or more inputs, determining one or more corrosion parameters of either an internal pipe wall, an external pipe surface, or both, applying a corrosion correlation value to the one or more corrosion parameters to produce one or more correlated corrosion parameters, and storing the one or more correlated corrosion parameters on a computer readable medium. A system may comprise an information handling system which may comprise at least one memory operable to store computer-executable instructions, at least one communications interface to access the at least one memory, and at least one processor.

AUTOMATED PUMP TRUCK CONFIRMATION TEST

A method of determining a health status of the various components of the pumping equipment on a pump unit may comprise an automatic diagnostic process with one or more diagnostic tests executing on a unit controller. One or more of the diagnostic tests can establish a flow path through the piping network comprising a supply pump and a sensor valve. The diagnostic test can include positioning the sensor valve in a first and second position while operating the pump to communicate a fluid via the flow loop. The method includes comparing a set of results of the diagnostic test to an operational indicator set, determining the health status based upon the comparison, and outputting indicia of the health status of the pumping equipment.

RATE OF PENETRATION DRILLING OPERATION CONTROLLER

СПОСОБ И СИСТЕМА КОМБИНИРОВАННОГО СОПРОВОЖДЕНИЯ ПРОЦЕССА БУРЕНИЯ СКВАЖИНЫ

Заявленное решение относится к способам и системам компьютерной обработки специализированных данных для обеспечения процесса сопровождения бурения скважин. Техническим результатом является повышение точности моделирования процесса проводки скважины в рамках целевого интервала с контролем устойчивости ствола скважины. Заявленный способ комбинированного сопровождения процесса бурения скважины заключается в выполнении этапов, на которых: получают входные данные разрабатываемой скважины, включающие в себя по меньшей мере данные инклинометрии, данные ГИС и данные керна;получают каротажные данные по меньшей мере одной опорной скважины;формируют на основании упомянутых входных данных и каротажных данных по меньшей мере одной опорной скважины комбинированную модель, отображающую характеристики пород и прогнозирование положения ствола разрабатываемой скважины; определение по меньшей мере одной плановой траектории направления бурения разрабатываемой скважины на основании каротажных данных по меньшей ...

СПОСОБ И УСТРОЙСТВО ДЛЯ ОЦЕНКИ СКОРОСТИ ВРАЩЕНИЯ И КРУТЯЩЕГО МОМЕНТА НА ЗАБОЕ СКВАЖИНЫ ДЛЯ СКВАЖИННОГО БУРОВОГО ОБОРУДОВАНИЯ ПРИ БУРЕНИИ, СКВАЖИННОЕ ОБОРУДОВАНИЕ И КОМПЬЮТЕРНЫЙ ПРОГРАММНЫЙ ПРОДУКТ

УСОВЕРШЕНСТВОВАННОЕ СТРУКТУРНОЕ МОДЕЛИРОВАНИЕ

СПОСОБ И УСТРОЙСТВО ДЛЯ ВЕРИФИКАЦИИ МОДЕЛИ СКВАЖИНЫ

Bestimmen von Premeabilität in unterirdischen anisotropen Formationen

... [00115] Ein Verfahren und ein System können einen Sensor beinhalten, der in einem Bohrloch positioniert ist, Charakteristiken der Erdformation können von dem Sensor gemessen und geloggt werden und eine effektive Permeabilität kann auf Grundlage der geloggten Charakteristiken bestimmt werden. Mehrkomponenteninduktions(MCI)-Daten können von einem Vermessungswerkzeug gemessen werden, 3D-Widerstandskomponenten können durch Invertieren der MCI-Daten bestimmt werden und die 3D-Widerstandskomponenten können geloggt werden. Triaxiale Permeabilitätskomponenten können auf Grundlage der effektiven Permeabilität und der 3D-Widerstandskomponentenlogs bestimmt werden. Eine Permeabilität von Sand in der Erdformation kann auf Grundlage der triaxialen Permeabilitätskomponenten, der effektiven Permeabilität und eines laminierten Schiefervolumens bestimmt werden. Die Sandpermeabilität kann geloggt werden und auf Grundlage der Sandpermeabilität können Modifikationen an einem oder mehreren Vorgängen eingeleitet ...

Integrated oilfield asset modeling using multiple resolutions of reservoir detail

Method of calculating temperature and porosity of geological structure

A method comprises inverting at least two geophysical parameters to estimate the temperature and/or porosity of a geological structure. One or more models (e.g. rock physics models) may be used in which there is statistical independence between the geophysical parameters and statistical dependence between each respective geophysical parameter and the temperature and/or porosity. The geophysical parameters may be obtained by inverting two types of geophysical data. The geophysical parameter values can be obtained by surface measurements. The parameters may be density, seismic velocity, magnetic susceptibility, electrical conductivity or resistivity, or magnetic remanence. A spatially dependent function of temperature and/or porosity may be determined. The temperature and/or porosity may be used in the decision making process for the drilling of a geothermal well.

Tool-specific steering optimization to hit a target

Extended isenthalpic and/or isothermal flash calculation for hydrocarbon componets that are soluble in oil, gas and water

Drilling with cuttings density calibration

A drilling operation can be optimized based on feedback provided by density sensors in a flow pipe. The drilling can be in a wellbore penetrating a subterranean formation while circulating a drilling fluid. The sensor can be used to detect an actual density of cuttings in the drilling fluid and within a region of the flow pipe. A modelled density of the cuttings can be calculated for the region based on an initial model. The initial model can be based on a comparison of an equivalent circulating density profile to a fracture gradient of the subterranean formation. Based on a comparison of the actual density of the cuttings to the modelled density of the cuttings, the initial model can be adjusted to generate an adjusted model. At least one operational parameter of the drilling can be changed based on the adjusted model.

Well operations involving synthetic fracture injection test

A system includes a processing device and a non-transitory computer-readable medium having instructions stored thereon that are executable by the processing device to cause the system to perform operations. The operations include generating and running a reservoir simulation model. The reservoir and simulation model includes representative natural fracture or secondary porosity attributes for an area of interest for one or more wells. The operations also include generating a synthetic G-function response using results of the reservoir simulation model. Additionally, the operations include calibrating the synthetic G-function response from the reservoir simulation model to a field G-function response generated using results of a field diagnostic fracture injection test by changing natural fracture characteristics of the reservoir simulation model. Further, the operations include formulating a drilling plan, a completion plan, or both for a wellbore in the area of interest using the synthetic ...

Cutting structure design with secondary cutter methodology

A method for performing oilfield production operations

Segmentation of time-frequency signatures for automated pipe defect discrimination

Techniques for extraction of vectorized content of an oil and gas play with an unstructed file

Controlling redistribution of suspended particles in non-newtonian fluids during stimulation treatments

System and methods for controlling suspended particle redistribution during stimulation treatments. Fluid flow in a wellbore is simulated for a stimulation treatment to be performed along a section of the wellbore within a subterranean formation, based on a flow model associated with the wellbore. Based on the simulation, dimensionless parameters characterizing a flow of suspended particles within a treatment fluid to a fractured area of the formation via at least one perforation along the section of the wellbore are calculated. A collection efficiency of the suspended particles within the fluid is determined, based on the dimensionless parameters. The collection efficiency is used to calculate a flow rate of the suspended particles to the fractured area of the formation via the perforation. The flow rate is used to estimate an amount of the suspended particles to be injected into the wellbore during the stimulation treatment along the wellbore section.

Automated fluid system

Method and apparatus for production logging tool (PLT) results production (PLT)

Extended isenthalpic and/or isothermal flash calculation for hydrocarbon componets that are soluble in oil, gas and water

Well operations involving synthetic fracture injection test

A hybrid deep physics neural network for physics based simulations

Aspects of the subject technology relate to systems and methods for predicting physical characteristics of a physical environment using a physical characterization model trained based on simulated states of a modeled physical environment. A physical characterization model can be generated based on a plurality of simulated states of a modeled physical environment. Specifically, the physical characterization model can be trained by mapping simulated spatial properties of the modeled physical environment temporally across the plurality of simulated states of the modeled physical environment. Further, input state data describing one or more input states of a physical environment can be received. One or more physical characteristics of the physical environment can be predicted by applying the physical characterization model to the one or more input states of the physical environment.

Analysis system and method for designing and correcting water curtain system of underground water-sealed oil storage

An analysis system and method for designing and correcting a water curtain system of an underground water-sealed oil storage, providing a method basis for design, construction and operation of the water curtain system of the underground water-sealed oil storage, combining geological exploration data and existing related research cases, and obtaining related parameter data required by the solution in an indoor test. The specific parameter selection range of the water curtain system is rapidly and accurately reduced by means of a finite element analysis method, the final design and construction solution is determined, accuracy and time saving are achieved, feasibility is high, and the oil leakage rate is low.

Model parameter reductions and model parameter selection to optimize execution time of reservoir management workflows

An apparatus for generating forecasts from a high-dimensional parameter data space comprising a reservoir model, a model order reduction module, and an assisted history matching module. The reservoir model having input variables, output variables, and an algorithmic model. The input variables, output variables, and the algorithmic model are generated by a flow simulator module and from a formation and reservoir properties database and a field production database. The model order reduction module generates a subset of the original or transformed input variables. This subset has a reduced parameter space than that of the input variables. The subset is generated using a function decomposition and a design of experiments (sensitivity analysis) to reduce number of original variables and identify original or transformed input variables that can be used to approximate output variables. The assisted history matching module adjust values of the output variables based on a difference between the ...

Park position for a survey tool

A gyroscope assembly is maintained in a park position during drilling activities. In the park position, a sensitive axis of a gyroscope in the gyroscope assembly is perpendicular or approximately perpendicular to a longitudinal axis of a downhole tool. Maintaining the park position during drilling activities reduces the drift bias caused by overloading the input signal of the gyroscope due to rotation of the downhole tool.

A tool, system and a method for determining barrier and material quality behind multiple tubulars in a hydrocarbon wellbore

A cement evaluation tool (100) comprises a body (2); a plurality of moveable assemblies (labc) having multiple arms (4) configured to move between a retracted position where the arms (4) are within a housing (3) and an extended position where the arms (4) are protruding from the housing (3) and are in contact with the inner wall of the downhole tubular element, wherein the assembly (la) comprises an acoustic broad band source array that operates in the frequency range of 0- 100 kHz and at assemblies (1b, 1c) comprise an acoustic broad band receiver array comprising one or more radially spaced acoustic broad band receivers (6). A method of determining cement bond quality behindmultiple tubulars comprises the steps of: conveying the tool into the well, activating the acoustic sources in order to trigger wave modes on the inner wall of the downhole tubular, recording wave modes excited on the inner wall of the downhole tubular, determining the eigenfrequencies of the excited wave modes, constructing ...

Method to engineer dependability into abandonment/kick-off plugs

A system and method comprising utilizing numerical analysis to determine the dependability of plug formulations and locations in wells. The plugs are typically used for abandonment or kick-off purposes. The system and method rely on defining initial physical and material properties, generating a geometric model, and applying loads and boundary conditions to the model. The numerical analysis is preformed to determine stress or deformation for the components of the well, thus providing a basis for selecting a suitable well plug formulation and location.

SIMULATION METHOD FOR FLOW FIELD OF MULTI-STAGE FRACTURING ON HORIZONTAL WELL IN TIGHT OIL RESERVOIR

The present invention aims at providing a simulation method for flow field of multi-stage fracturing on horizontal well in tight oil reservoir, which comprises establishing a mathematical model of seepage considering the threshold pressure gradient and deriving the pressure distribution formula after fracturing; based on the principle of complex potential superposition, calculating the pressure field distribution of multi-stage fracturing on horizontal well in tight oil reservoir; and establishing a criterion for identifying the effective producing range of multi-stage fracturing on horizontal well in tight oil reservoir to accurately simulate the flow field range of multi-stage fracturing in tight oil reservoir. Regardless of the excitation 500 effect between the fractures. Considering the excitation effect between the fractures. Ce200 0 50 100 150 200 Distance(m) Figure Regardless of the excitation 500 effect between the fractures. Considering the excitation effect between the fractures ...

Reservoir history matching

Systems and methods for reservoir history matching based on closed loop interaction between a geomodel and a reservoir model.

Determining well integrity

A method performed with a computing system for determining well integrity includes receiving a selection of a well configuration of a well comprising one or more casing strings and a production tubing extending from adjacent a wellhead of the well to adjacent a bottom of the well; receiving a selection of a wellbore operation performed with the well configuration; determining, based on the well configuration and the wellbore operation, a characteristic of the well at or adjacent the one or more casing strings and the production tubing during the wellbore operation; modifying the well configuration to remove the production tubing; and determining, based on the modified well configuration and the wellbore operation, the characteristic of the well at or adjacent the one or more casing strings during the wellbore operation.

METHOD FOR SELECTION OF IMPROVED HYDROCARBON RECOVERY AGENTS FOR HYDROCARBON REVERVOIRS

A physical modeling method that includes providing a reservoir core plug, the reservoir core plug having a wellbore interface end, an outlet interface end, and a cylindrical face and saturating the reservoir core plug with hydrocarbon and brine to fonn a saturated core plug. The method also includes positioning the saturated core plug within a flooding apparatus and pumping the fracturing fluid through saturated core plug to displace a portion of the hydrocarbon to fonn a displaced hydrocarbon plug. In addition the method includes positioning the displaced hydrocarbon plug in an imbibition cell and conducting an imbibition test to fonn an imbibed core plug having brine and hydrocarbon. Further the method includes positioning the imbibed core plug in core-flooding apparatus and displacing a portion of the brine and hydrocarbon from the imbibed core plug.

REAL-TIME CALIBRATION OF EXCITATION RANGING FOR TRACKING WELLBORE DRILLING

A method includes generating a ranging model of a drilling wellbore to be drilled and generating a predicted signal along measured depths of the drilling wellbore based on the ranging model. The method includes performing the following operations until the drilling wellbore has been drilled to a defined depth. The following operations include drilling, with a drill string, the drilling wellbore to an increment of the defined depth and detecting, by a sensor positioned on the drill string, an electromagnetic field emanating from a target wellbore. The following operations include determining ranging measurements to the target wellbore at the increment based on the electromagnetic field and calibrating the predicted signal based on the ranging measurements. The following operations include determining ranging accuracy for all deeper depths in the wellbore and making drilling decisions or adjusting drilling operations based on the predicted ranging accuracy for deeper depths.

A FLOW SIMULATION AND TRANSIENT WELL ANALYSIS METHOD BASED ON GENERALIZED TUBE FLOW AND PERCOLATION COUPLING

Disclosed is a flow simulation and transient well analysis method based on a generalized pipe flow seepage coupling. The method comprises the following steps: S1: defining generalized fluidity to characterize, by means of generalized fluidity models with the same form, flow laws of a fluid in different subsets of a research area; S2: on the basis of the generalized fluidity, establishing a multi-component and multi-phase-flow flow simulation equation, solving the multi-component and multi-phase-flow flow simulation equation, and obtaining the pressure, temperature and saturation of a multi-component and multi-phase-flow fluid in the research area and the molar percentage of each component in each phase; and S3: forming corresponding application software by means of an established multi-component and multi-phase-flow flow simulation and analysis equation. The present invention plays an important role in solving the problems of flow simulation and analysis, inter-well interference analysis ...

AUTOMATED PRODUCTION HISTORY MATCHING USING BAYESIAN OPTIMIZATION

A history-matched oilfield model that facilitates well system operations for an oilfield is generated using a Bayesian optimization of adjustable parameters based on an entire production history. The Bayesian optimization process includes stochastic modifications to the adjustable parameters based on a prior probability distribution for each parameter and a model error generated using historical production measurement values and corresponding model prediction values for various sets of test parameters.

SYSTEMS AND METHODS FOR ESTIMATING RESERVOIR PRODUCTIVITY AS A FUNCTION OF DEPTH IN A SUBSURFACE VOLUME OF INTEREST

Systems and methods for estimating reservoir productivity as a function of depth in a subsurface volume of interest are disclosed. Exemplary implementations may: obtain subsurface data and well data corresponding to a subsurface volume of interest; obtain a parameter model; use the subsurface data and the well data to generate multiple production parameter maps; apply the parameter model to the multiple production parameter maps to generate refined production parameter values; generate multiple refined production parameter graphs; display the multiple refined production parameter graphs; generate one or more user input options; receive the one or more user input options selected by a user to generate limited production parameter values; generate a representation of estimated reservoir productivity as a function of depth in the subsurface volume of interest using visual effects; and display the representation.

DOWNHOLE DRILLING METHODS AND SYSTEMS WITH TOP DRIVE MOTOR TORQUE COMMANDS BASED ON A DYNAMICS MODEL

A drilling system includes a top drive having a motor with a rotating shaft and an adjustable torque. The drilling system also includes a connector that couples the rotating shaft to a drillstring. The drillstring system also includes a controller that provides torque commands to the motor, wherein the torque commands are based at least in part on a dynamics model and operate to dampen vibrations due to torsional wave propagation along the drillstring.

DEFINING NON-LINEAR PETROFACIES FOR A RESERVOIR SIMULATION MODEL

System and methods for defining non-linear petrofacies for a reservoir simulation model are provided. A cross-plot visualization of selected petrophysical properties from a three-dimensional (3D) geocellular grid array of petrophysical properties representing a reservoir rock formation is presented to a user via a display of a computing device. Upon receiving user input for defining a non-linear petrofacies region of the 3D geocellular grid within the presented cross-plot visualization, data points in the cross-plot visualization that are within the boundaries of the petrofacies region are identified. The identified data points are associated with the petrofacies region. Hydraulic rock properties are assigned to one or more cells of the 3D geocellular grid based on the data points associated with the petrofacies region.

WELL OPERATIONS INVOLVING SYNTHETIC FRACTURE INJECTION TEST

A system includes a processing device and a non-transitory computer-readable medium having instructions stored thereon that are executable by the processing device to cause the system to perform operations. The operations include generating and running a reservoir simulation model. The reservoir and simulation model includes representative natural fracture or secondary porosity attributes for an area of interest for one or more wells. The operations also include generating a synthetic G-function response using results of the reservoir simulation model. Additionally, the operations include calibrating the synthetic G-function response from the reservoir simulation model to a field G-function response generated using results of a field diagnostic fracture injection test by changing natural fracture characteristics of the reservoir simulation model. Further, the operations include formulating a drilling plan, a completion plan, or both for a wellbore in the area of interest using the synthetic ...

APPLICATION OF THE ENSEMBLE KALMAN FILTER TO DYNAMIC HISTORY MATCHING IN WELLBORE PRODUCTION

A method for identifying a flow parameter in a wellbore may comprise identifying a state vector at a moment t, performing a flow simulation using a flow model, predicting the state vector and a covariance matrix at the moment t, updating the state vector with an EnKF algorithm, correcting the state vector at the moment t, and updating the flow simulation model. A system for identifying a flow parameter in a wellbore may comprise a distributed acoustic system into a wellbore and an information handling system. The distributed acoustic system may comprise a fiber optic cable and at least one measurement device.

CONVEYANCE MODELING

A conveyance model 710 for predicting an output 730 in response to an input, wherein: the input comprises one or more of a wireline input 722, a toolstring input 724, a well input 726, and/or a conveyance input 728; and the output comprises one or more of a surface weight versus depth output, a cable head tension versus depth output, and a jarring effect output.

METHOD AND SYSTEM FOR NON-INTRUSIVELY DETERMINING DEPOSITS IN A FLUIDIC CHANNEL

A method is provided for non-intrusively determining deposits in a fluidic channel. The method includes obtaining,from one or more sensors, a measured pressure profile based on at least one pressure pulse induced in a fluidic channel; generating a forward model of deposits in the fluidic channel; and generating, using the forward model, a simulated pressure profile. An error is calculated using the measured pressure profile and the simulated pressure profile, and when the error is outside a predetermined threshold, the forward model is updated. The updated forward model is adjusted based on the error.

METHODS FOR ESTIMATING HYDRAULIC FRACTURE SURFACE AREA

Methods for estimating fluid leak-off rate and the associated hydraulic fracture surface area originated from a wellbore, are provided. A pressure gauge is connected to the wellbore to monitor pressure during and after hydraulic fracturing operations. A fracture pressure is identified, where identified fracture pressure is larger than a formation pore pressure and smaller than a fracture propagation pressure. Injection rate of an injection fluid is regulated to a created hydraulic fracture to maintain constant fracture pressure, such that created hydraulic fracture maintains its current dimensions and injection rate of injection fluid into created hydraulic fracture equals total fluid leak-off rate from created hydraulic fracture, wherein the constant fracture pressure equals identified fracture pressure. A fluid leak-off model is utilized to estimate surface area of the created hydraulic fracture, where the fluid leak-off model provides the relationship between total fluid leak-off rate ...

OPTIMIZED REPAIR OF A DRILL BIT

A method for repairing a drill bit includes: scanning the drill bit after manufacture thereof; comparing the scan to a design model of the drill bit to recognize one or more features of the drill bit, thereby generating a first model of the as-built drill bit; scanning the drill bit after drilling with the drill bit; comparing the scan of the used drill bit to the first model to recognize the features, thereby generating a second model of the used drill bit; simulating a plurality of repair strategies using the first and second models; and selecting one of the repair strategies by comparing results of the simulations.

Method for exploiting a geological reservoir from a reservoir model matched by the computation of an analytical law of conditional distribution of uncertain parameters of the model

The invention is a method for exploiting a geological reservoir to exploit hydrocarbons or provide gas storage. The exploitation is defined on the basis of a reservoir model calibrated relative to dynamic data. The calibration is carried out by computing an objective function for a set of reservoir models. The objective function makes it possible to determine an analytical law of conditional distribution of the uncertain parameters of the model to generate new reservoir models added to the set of reservoir models.

FRACTURING OPERATIONS PUMP FLEET BALANCE CONTROLLER

A system can include one or more processors; memory; a data interface that receives data; a control interface that transmits control signals for control of pumps of a hydraulic fracturing operation; and one or more components that can include one or more of a modeling component that predicts pressure in a well fluidly coupled to at least one of the pumps, a pumping rate adjustment component that generates a pumping rate control signal for transmission via the control interface, a capacity component that estimates a real-time pumping capacity for each individual pump, and a control component that, for a target pumping rate for the pumps during the hydraulic fracturing operation, generates at least one of engine throttle and transmission gear settings for each of the individual pumps using an estimated real-time pumping capacity for each individual pump where the settings are transmissible via the control interface. 12800. A system () comprising:{'b': '2810', 'one or more processors ();'}{'b': '2820', 'memory () accessible to at least one of the one or more processors;'}{'b': '2830', 'a data interface () that receives real-time data for individual pumps in a fleet of pumps during a hydraulic fracturing operation;'}{'b': '2840', 'a control interface () that transmits control signals for control of each of the individual pumps in the fleet of pumps during the hydraulic fracturing operation;'}{'b': '2870', 'a capacity component (), operatively coupled to at least one of the one or more processors, that estimates a real-time pumping capacity for each of the individual pumps in the fleet of pumps using at least a portion of the real-time data, wherein an estimated real-time pumping capacity for the fleet of pumps computed using the estimates is less than a maximum specified pumping capacity for the fleet of pumps due to operational degradation of at least one of the individual pumps; and'}{'b': '2880', 'a control component (), operatively coupled to at least one of the one ...

Estimating relative permeability and capillary pressures of a geological formation based on multiphase upscaling

A system can access geological data describing a plurality of rock types in a physical rock sample drilled from a reservoir. The system can generate synthetic rock samples and execute single phase upscaling to compute absolute permeabilities for the physical rock sample and the synthetic rock samples. The system can execute a first multiphase upscaling based on the single phase upscaling to determine relative permeabilities for the physical rock sample and the synthetic rock samples. The system can compare the relative permeability of the physical rock sample to the relative permeabilities for the synthetic rock samples and select a synthetic rock sample that varies the least from the physical rock sample. The system can perform at least one additional multiphase upscaling on the physical rock sample and the synthetic rock samples to determine a second multiphase upscaling result and to develop a plan for drilling operations.

Compositions and Methods for Pressure Protection

Disclosed are compositions and methods for the pressure protection of existing wells during infill drilling operations. 1. A method for pressure protection of an existing wellbore that has previously been fractured in proximity to a new wellbore to be fractured , the method comprising:injecting a foamed pressure protection composition into the existing wellbore in fluid communication with an unconventional subterranean formation prior to and/or during fracturing of the new wellbore in fluid communication with the unconventional subterranean formation;wherein the existing wellbore has an existing reservoir pressure that is less than original reservoir pressure; andwherein the foamed pressure protection solution is injected at a pressure and flowrate effective to increase the existing wellbore pressure without refracturing the existing wellbore.2. The method of claim 1 , wherein the existing wellbore was under production for at least three months prior to injection of the foamed pressure protection composition claim 1 ,optionally wherein at least 10,000 barrels of hydrocarbon were produced from the existing wellbore prior to injection of the foamed pressure protection composition.3. The method of claim 1 , wherein the existing wellbore pressure is from 20% to 70% of the original reservoir pressure.4. The method of claim 1 , wherein injecting the foamed pressure protection composition comprises injecting the foamed pressure protection composition at a pressure and flowrate effective to increase the existing wellbore pressure by at least 30% claim 1 , to increase the existing wellbore pressure to from greater than the original reservoir pressure to 150% of the original reservoir pressure claim 1 , to increase the existing wellbore pressure to within 15% of original reservoir fracture pressure claim 1 , or any combination thereof.5. The method of claim 1 , wherein the foamed pressure protection composition is injected at least 1 day before fracturing claim 1 , such as at ...

Compositions and Methods for Pressure Protection

Disclosed are compositions and methods for the pressure protection of existing wells during infill drilling operations. 1. A method for pressure protection of an existing wellbore that has previously been fractured in proximity to a new wellbore to be fractured , the method comprising:injecting a gas into the existing wellbore in fluid communication with an unconventional subterranean formation prior to and/or during fracturing of the new wellbore in fluid communication with the unconventional subterranean formation;wherein the existing wellbore has an existing reservoir pressure that is less than original reservoir pressure; andwherein the gas is injected at a pressure and flowrate effective to increase the existing wellbore pressure without refracturing the existing wellbore.2. The method of claim 1 , wherein the existing wellbore was under production for at least three months prior to injection of the gas claim 1 ,optionally wherein at least 10,000 barrels of hydrocarbon were produced from the existing wellbore prior to injection of the gas.3. The method of claim 1 , wherein the existing wellbore pressure is from 20% to 70% of the original reservoir pressure.4. The method of claim 1 , wherein injecting the gas comprises injecting the gas at a pressure and flowrate effective to increase the existing wellbore pressure by at least 30% claim 1 , to increase the existing wellbore pressure to from greater than the original reservoir pressure to 150% of the original reservoir pressure claim 1 , to increase the existing wellbore pressure to within 15% of original reservoir fracture pressure claim 1 , or any combination thereof.5. The method of claim 1 , wherein the method further comprises injecting a fracturing fluid into the unconventional subterranean formation via the new wellbore at a sufficient pressure to create or extend at least one fracture in a rock matrix of the unconventional subterranean formation in a region proximate to the new wellbore.6. The method of ...

Method for calculating single-well controlled reserve of low-permeability/tight gas reservoir and analyzing residual gas thereof

The present invention belongs to the technical field of oil and gas field development, and discloses a method for calculating a single-well controlled reserve of a low-permeability/tight gas reservoir and analyzing residual gas thereof. The method includes: calculating a reserve controlled by each gas well in a block by using a gas reservoir dynamic reserve calculation method; establishing a new reserve calculation formula for solution and comparative analysis by an example; and quantitatively analyzing an effect of a startup pressure gradient and a stress sensitivity on a calculation result of the single-well controlled reserve, wherein the analysis of the factors affecting reserve calculation shows that, when the startup pressure gradient reaches 0.02 MPa/m, the calculated reserve is significantly reduced compared with a conventional method, but when the startup pressure gradient is greater than 0.1 MPa/m, the effect gradually stabilizes.

METHOD FOR IDENTIFYING A MEDIUM STRUCTURE COUPLING AND A FRACTURE NETWORK MORPHOLOGY OF A SHALE GAS RESERVOIR

A method for identifying a medium structure coupling and a fracture network morphology of a shale gas reservoir includes the following steps. Firstly, performing a fracturing test on shale cores by using a modified Brazilian disc test and categorizing the fracture network morphology. Secondly, performing a shale matrix-fracture structure and stress sensitivity test on the shale cores having different fracture network morphology. After that, determining a stress sensitivity constant of different fracture network morphology according to indoor core data and finally preparing an identification chart of the fracture network morphology based on an indoor core stress sensitivity text combined with a production practice. The identification chart can be applied to an actual fracturing well, and the fracture network morphology is directly identified by a real-time effective stress and a normalized flow. 1. A method for identifying a medium structure coupling and a fracture network morphology of a shale gas reservoir , comprising the following steps:(1) categorizing the fracture network morphology: performing a fracturing test on shale cores by using a modified Brazilian disc test, categorizing the fracture network morphology as a tree-like fracture network, a feather-like fracture network, a tufted fracture network, and a meshed fracture network;(2) performing a shale matrix-fracture structure and stress sensitivity test: selecting the shale cores having different fracture network morphology in the step (1), performing the shale matrix-fracture structure and stress sensitivity test on the shale cores by a core displacement experiment, recording parameters of permeability and effective stress of the shale core;(3) determining a stress sensitivity constant of different fracture network morphology: according to the parameters of the permeability and the effective stress of the shale cores having the different fracture morphology in the step (2) under different stress conditions ...

Simulation Method for Flow Field of Multi-Stage Fracturing on Horizontal Well in Tight Oil Reservoir

A simulation method for flow field of multi-stage fracturing on horizontal well in tight oil reservoir is provided. The tight oil reservoir comprises multiple horizontal wells with multi-stage fracturing, and for any horizontal well of the multiple horizontal wells, the method comprises: establishing a seepage mathematical model involving threshold pressure gradient according to reservoir physical property data and production data of the horizontal well, and determining formation pressure distribution of the horizontal well after multi-stage fracturing production according to the seepage mathematical model; determining formation pressure field distribution of the horizontal well after multi-stage fracturing production according to the formation pressure distribution and basing on principle of complex potential superposition; and establishing a criterion for identifying effective producing range of the horizontal well according to the formation pressure field distribution, and determining flow field range of the horizontal well according to the criterion. 1. A simulation method for flow field of multi-stage fracturing on horizontal well in tight oil reservoir , the tight oil reservoir comprises multiple horizontal wells with multi-stage fracturing , and for any horizontal well of the multiple horizontal wells , the method comprises:establishing a seepage mathematical model involving threshold pressure gradient according to reservoir physical property data and production data of the horizontal well, and determining formation pressure distribution of the horizontal well after multi-stage fracturing production according to the seepage mathematical model;determining formation pressure field distribution of the horizontal well after multi-stage fracturing production according to the formation pressure distribution and basing on principle of complex potential superposition; andestablishing a criterion for identifying effective producing range of the horizontal well ...

OPTIMIZATION OF DISCRETE FRACTURE NETWORK (DFN) USING STREAMLINES AND MACHINE LEARNING

A methodology is provided to optimize the dynamic connectivity of a discrete fracture network (DFN) model of a subsurface reservoir against observed reservoir production measures using streamlines and machine learning. Adjustment of discrete fracture network properties of the reservoir is made locally and minimizes computer processing time spent in history matching. An iterative workflow identifies history match issues between measured and predicted or simulated water cut of reservoir produced fluids. Streamline analysis quantifies injector-producer communication and identifies reservoir grid block bundles that dominate dynamic response. A genetic algorithm updates discrete fracture network properties of the reservoir model to improve dynamic history match response. 1. A method of determining a location for drilling a well in a subsurface geological structure of a subsurface hydrocarbon reservoir having existing wells producing fluids comprising hydrocarbons and exhibiting water cut representing water mixed in the fluids being produced , the location being determined indicated by an optimized natural fracture network model of the reservoir , comprising the steps of:(a) obtaining reservoir parameters representing properties of the subsurface reservoir for processing in a data processing system, the reservoir properties including observed cumulative water cut of the produced fluids during production from the existing wells;(b) forming a proposed discrete fracture network model indicating the nature and extent of discrete fractures and fracture flow paths in the reservoir;(c) performing a reservoir simulation history match from the obtained reservoir parameters to determine simulated cumulative water cut of the fluids;(d) determining a measure of the difference between the determined simulated cumulative water cut from the performed reservoir simulation history match and the observed water cut of the produced hydrocarbon fluids from the existing wells;(e) determining ...

Fluid-solid coupling numerical simulation method for evaluating effect of wellbore strengthening in fractured formation

A fluid-solid coupling numerical simulation method for evaluating the effect of wellbore strengthening in a fractured formation includes steps of: establishing an elastic deformation equation of rocks around the wellbore; establishing and solving the fluid flow equations within fractures and plugging zone, respectively; substituting the discretized elastic deformation equation of the rocks around the borehole wall into the fluid flow equations of fractures to obtain a fluid-solid coupling equation set for wellbore strengthening in a fractured formation; and finally solving the fluid-solid coupling equation set; and substituting basic parameters into the fluid-solid coupling equation set, and simulating mechanical response characteristics, width evolution characteristics and flow distribution characteristics of plugged fractures under different parameter combinations. The present invention systematically considers the complex flow states of plugged fractures during wellbore strengthening, as well as the deformation and seepage characteristics plugging zone under multi-force coupling. 19-. (canceled)124. The fluid-solid coupling numerical simulation method claim 10 , as recited in claim 10 , wherein in the step S claim 10 , the basic parameters comprise in-situ stress parameters claim 10 , rock mechanics parameters claim 10 , fracture geometric parameters claim 10 , plugging zone geometric and permeability parameters claim 10 , a fluid viscosity and a displacement. The present invention claims priority under 35 U.S.C. 119(a-d) to CN 202010928300.1, filed Sep. 7, 2020.The present invention relates to a technical field of oil and gas exploration, and more particularly to a fluid-solid coupling numerical simulation method for evaluating an effect of wellbore strengthening in a fractured formation.With the global oil and gas exploration and development transiting to deep formations and unconventional oil and gas resources, the occurrence of drilling into broken formation, ...

PHYSICS-PRESERVING IMPES SCHEME AND SYSTEM

A physics-preserving, implicit pressure, explicit saturation method for simulation of incompressible and immiscible two-phase flow in heterogeneous porous media with capillary pressure, includes receiving input data that characterizes a given domain in a subsurface of the earth; selecting initial parameters K associated with a mixed finite element algorithm; modifying Darcy flows to include a total velocity uand a capillarity potential gradient ξ; establishing a total conservation equation by summing a discretized conservation equation for each phase α of the two-phase flow; and calculating at least one parameter based on the modified Darcy flows and the total conservation equation. The at least one parameter characterizes the two-phase flow in the heterogeneous porous media with a capillary pressure, between an injection well and a production well. 1. A physics-preserving implicit pressure explicit saturation method for simulation of incompressible and immiscible two-phase flow in heterogeneous porous media with capillary pressure , the method comprising:receiving input data that characterizes a given domain in a subsurface of the earth;selecting initial parameters K associated with a mixed finite element algorithm;{'sub': t', 'c, 'modifying Darcy flows to include a total velocity uand a capillarity potential gradient ξ;'}establishing a total conservation equation by summing a discretized conservation equation for each phase α of the two-phase flow; andcalculating at least one parameter based on the modified Darcy flows and the total conservation equation,wherein the at least one parameter characterizes the two-phase flow in the heterogeneous porous media with a capillary pressure, between an injection well and a production well.2. The method of claim 1 , wherein the at least one parameter includes one or more of a saturation for each phase claim 1 , a pressure for each phase claim 1 , or the total velocity of the flow.3. The method of claim 1 , wherein the input ...

METHOD FOR DEVELOPING A HYDROCARBON RESERVOIR BY INJECTING A GAS IN THE FORM OF FOAM

A method of developing a hydrocarbon reservoir by injecting an aqueous solution containing a gas in the form of foam into an injection well. A first step determines a foam displacement model for a flow simulator which is a function of a gas mobility reduction factor and of at least one injection rate-dependent interpolation function. A second step determines a productivity index corrected for the shear thinning effects of the foam in the cells traversed by the injection well, from a productivity index determined by assuming that the aqueous solution containing the gas in foam form is a Newtonian fluid, and a correction factor that is a function of at least one characteristic of the aqueous solution containing the gas in foam form. 112.-. (canceled)13. A method for exploiting hydrocarbons in a reservoir , by injection of an aqueous solution containing a gas form into at least one injection well and of a flow simulator , based on a displacement model of the gas form , the displacement model being expressed as a function of a mobility reduction function of the gas , the function being expressed as a function of a mobility reduction factor of the gas and at least one interpolation function of the mobility reduction factor , the interpolation function being a function of at least one parameter relative to at least one characteristic of the foam and of at least two constants , the at least one parameter of the interpolation function corresponding to an injection rate of the gas , from at least one sample of the formation and from a gridded representation representative of the reservoir , comprising steps of:A—determining the displacement model by determining the mobility reduction factor of the gas and the constants of the interpolation function of the displacement model, from at least pressure drop measurements performed while injecting into the at least one sample the gas in non-foaming form and the gas foam for values of the injection rate of the gas; {'br': None, 'i': ...

Hydraulic fracturing modelling and control

Aspects of the subject technology relate to systems and methods for controlling a hydraulic fracturing job. A fracturing completion model can be applied to identify a plurality of possible fracturing completion plans for completing one or more wellbores at a target completion. The plurality of possible fracturing completion plans can include varying values of fracturing completion parameters and/or reservoir parameters. Completion characteristic data of the one or more wellbores can be gathered in response to application of at least a portion of a fracturing completion plan of the possible fracturing completion plans. Further, the completion characteristic data can be used to determine whether to apply a different fracturing completion plan of the possible fracturing completion plans. In turn, if it is determined to apply the different fracturing completion plan, then the method can include facilitating switching to the different fracturing completion plan in completing the one or more wellbores.

Method and System of Producing Hydrocarbons Using Data-Driven Inferred Production

A method of predicting hydrocarbon production from one or more artificial lift wells is disclosed. Test data is obtained from the artificial lift well. A decline curve model, representing well performance, is generated for one or more fluids in the artificial lift well. Measurement values are obtained from an artificial lift operation. For each of the obtained measurement values, a measurement model is generated that correlates the measurement values to the decline curve. A Kalman filter is used to predict production outputs of at least one of oil, gas, and water for the well, and to generate an uncertainty range for the predicted production outputs. The Kalman filter uses the decline curves to predict the production outputs, and uses the measurement models to correct and/or update the predicted production outputs. Hydrocarbon production activities are modified using the corrected and/or updated predicted production outputs. 1. A method of predicting hydrocarbon production from an artificial lift well , comprising:obtaining test data from the artificial lift well using a well test;based on the obtained test data, generating a decline curve model for one or more fluids in the artificial lift well, the decline curve representing well performance;obtaining measurement values from an artificial lift operation;for each of the obtained measurement values, generating a measurement model that correlates the measurement values to the decline curve; predicting production outputs of at least one of oil, gas, and water for the well, and', 'generating an uncertainty range for the predicted production outputs;, 'using a Kalman filter,'} uses the decline curves to predict the production outputs, and', 'uses the measurement models to correct and/or update the predicted production outputs; and, 'wherein the Kalman filter'}modifying hydrocarbon production activities using the corrected and/or updated predicted production outputs.2. The method of claim 1 , wherein correcting and/or ...

METHOD AND APPARATUS FOR PREDICTING OPTIMAL EXPLOITATION IN SHALE OIL IN-SITU CONVERSION

The disclosure provides a method and apparatus for predicting an optimal exploitation approach for shale oil in-situ conversion. The method includes: determining a lower limit temperature required for completely converting convertible organic matter in a shale to be measured into oil and gas, based on a pre-established relationship between the temperature rise rate and the lower limit temperature; determining an optimal well distance of heating wells, based on a thermal field parameter of a target reservoir of interest, an optimal heating time corresponding to the lower limit temperature, and a pre-established relationship between an optimal well distance of heating wells and the optimal heating time; determining an oil yield equivalent based on a temperature and an oil yield equivalent of the shale; determining an optimal well pattern; the lower limit temperature, the optimal well distance of heating wells, the oil yield equivalent and the optimal well pattern are optimal parameters. 1. A method for predicting an optimal exploitation approach for shale oil in-situ conversion , comprising:determining a lower limit temperature required for completely converting convertible organic matter in a shale to be measured into oil and gas, based on a temperature rise rate and a pre-established relationship between the temperature rise rate and the lower limit temperature required for completely converting the convertible organic matter in the shale into oil and gas;determining an optimal well distance of heating wells, based on a thermal field parameter of a target reservoir of interest, an optimal heating time corresponding to the lower limit temperature, and a pre-established relationship between the optimal well distance of heating wells and the optimal heating time;determining an oil yield equivalent of a production well in the target reservoir of interest, based on the temperature rise rate and a pre-established relationship between a temperature and an oil yield ...

MEASURING SEALING QUALITY OF CONNECTIONS IN DOWNHOLE CASINGS

A method and system for inspecting casings in a wellbore to determine a mechanical or sealing quality of casing connections. Casing connections may become mechanically weak or start to leak after some period of use in harsh conditions. A radial array of ultrasound transducers images the casing in-situ to create an ultrasound image, which is analyzed to detect the casing connector then analyzed a sealing band of the connector. Machine learning and image processing methods may be used to analyze the images. 1. A method of inspecting a wellbore comprising:deploying an imaging tool into and axially through casings of the wellbore;imaging the casing with a radial array of ultrasound transducers to create an ultrasound image;analyzing the ultrasound image to detect features that identify a casing connector;locating a band of the ultrasound image at a predetermined offset from the detected features; andanalyzing the band of the image to determine a connection quality of the casing connector to the casing.2. The method of claim 1 , wherein the band is a sealing band next to the features which sealing band corresponds to a metal-to-metal sealing interface between the casing and a casing connector andwherein analyzing the band of the image comprises determining a sealing quality of the casing connector to the casing.3. The method of claim 1 , wherein the band corresponds to a plurality of threads connecting the casing and casing connector andwherein analyzing the band of the image comprises determining a mechanical connection strength of the casing connector to the casing.4. The method of claim 1 , wherein the feature of the casing connector is at least one of: threads claim 1 , a torque shoulder claim 1 , and a dope relief.5. The method of claim 1 , further comprising filtering out reflections in the ultrasound image from the inner and/or outer surfaces of the casing.6. The method of claim 1 , further comprising converting a magnitude of reflection energy in the ultrasound ...

METHODS AND SYSTEMS FOR PREDICTING INTERFACIAL TENSION OF RESERVOIR FLUIDS USING DOWNHOLE FLUID MEASUREMENTS

Methods and systems are provided for characterizing interfacial tension (IFT) of reservoir fluids, which involves obtaining fluid property data that represents fluid properties of a reservoir fluid sample measured downhole at reservoir conditions, and inputting the fluid property data to a computational model that determines a value of oil-water IFT of the reservoir fluid sample based on the fluid property data. In embodiments, the fluid property data represents single-phase fluid properties of the reservoir fluid sample, such as fluid density and viscosity of an oil phase of the reservoir fluid sample and fluid density of a water phase of the reservoir fluid sample. In embodiments, the computation model can be based on machine learning or analytics combined with a thermodynamics-based physics model. 1. A method for characterizing interfacial tension (IFT) of reservoir fluids , comprising:a) obtaining fluid property data that represents fluid properties of a reservoir fluid sample measured downhole at reservoir conditions; andb) inputting the fluid property data to a computational model that determines a value of oil-water IFT of the reservoir fluid sample based on the fluid property data.2. A method according to claim 1 , wherein:the operations of a) and b) are performed by a processor.3. A method according to claim 2 , wherein:the processor is part of a cloud-based computing environment.4. A method according to claim 1 , further comprising:storing the value of the oil-water IFT of the reservoir fluid sample as part of data accessible by an advisory tool for reservoir analysis and optimization.5. A method according to claim 4 , wherein:the advisory tool is provided by a cloud-based computing environment for reservoir analysis and optimization.6. A method according to claim 1 , wherein:the fluid property data represents single-phase fluid properties of the reservoir fluid sample.7. A method according to claim 6 , wherein:the single-phase fluid properties of the ...

Characterizing low-permeability reservoirs by using numerical models of short-time well test data

Systems and methods include a computer-implemented method for characterizing low-permeability reservoirs by using numerical models. A numerical model modeling production of a well is prepared using reservoir data and well data. The numerical model is updated, including adjusting numerical model properties, until results of performing a quality assurance/quality control check indicate that the numerical model is within acceptable limits. Pressure derivatives are extracted from a transient test to create a functional numerical model. Simulations are run on the functional numerical model and reservoir features and properties are adjusted until acceptable results are achieved on: 1) a pressure match between pressures modeled in the functional numerical model and transient pressures of the well, and 2) a log-log plot derivative match between a pressure derivative of the functional numerical model and a pressure derivative of the transient pressures of the well. A simulation output that is based on the simulations is provided.

METHOD OF CALCULATING TEMPERATURE AND POROSITY OF GEOLOGICAL STRUCTURE

A method of calculating the temperature and/or porosity of a geological structure, wherein there is provided at least two geophysical parameters of the geological structure, the method including inverting the at least two geophysical parameters to estimate the temperature and/or porosity of the geological structure. 1. A method of calculating the temperature and/or porosity of a geological structure , wherein there is provided at least two geophysical parameters of the geological structure , the method comprising:inverting the at least two geophysical parameters to estimate the temperature and/or porosity of the geological structure; andusing the calculated temperature and/or porosity in the decision-making process for the drilling of a geothermal well.2. A method as claimed in comprising using both the calculated temperature and the calculated porosity in the decision-making process for the drilling of a geothermal well.3. A method as claimed in claim 1 , wherein the at least two geophysical parameters are any geophysical parameters which are dependent on temperature and/or porosity claim 1 , such as density claim 1 , seismic velocity claim 1 , magnetic susceptibility claim 1 , electrical conductivity claim 1 , electrical resistivity or magnetic remanence.4. A method as claimed in claim 3 , wherein the at least two geophysical parameters comprise electrical conductivity.5. A method as claimed in claim 1 , wherein the inverting step comprises using one or more models in which there is statistical independence between the at least two geophysical parameters and statistical dependence between each respective geophysical parameter and the temperature and/or porosity of the geological structure.6. A method as claimed in claim 1 , wherein the inverting step comprises using respective forward models for each respective geophysical parameter claim 1 , the forward models each defining a relationship between the respective geophysical parameter and the temperature and/or ...

Geologic formation operations framework control

A method can include accessing data generated during field operations; analyzing at least a portion of the data as to legal tag property values; storing the legal tag property values in association with the data; and operating a computational framework in accordance with the legal tag property values.

Systems and Methods for Predicting the Composition of Petroleum Hydrocarbons

A quantitative simulation process for producing quantitative model predictions of hydrocarbon composition may comprise: measuring a chemical and isotopic composition of a hydrocarbon sample from a hydrocarbon reservoir; measuring geochemical data, geophysical data, and/or geological data for the hydrocarbon reservoir and/or source rock; deriving temperature versus time relationships from a basin model for the hydrocarbon reservoir and/or source rock based on the geochemical data, geophysical data, and/or geological data; generating estimated source-rock maturity parameters based on the temperature versus time relationships; generating an estimated compositional yield for hydrocarbon fractions based on the temperature versus time relationships and the chemical composition of the hydrocarbon sample; and generating, using a mass-conserving isotopic fraction (MCIF) simulator, an estimated isotopic composition of the hydrocarbon fractions based on the estimated compositional yield and the isotopic composition of the hydrocarbon sample. 1. A process comprising:measuring a chemical and isotopic composition of a hydrocarbon sample from a hydrocarbon reservoir;measuring geochemical data, geophysical data, and/or geological data for the hydrocarbon reservoir and/or source rock;deriving temperature versus time relationships from a basin model for the hydrocarbon reservoir and/or source rock based on the geochemical data, geophysical data, and/or geological data;generating estimated source-rock maturity parameters based on the temperature versus time relationships;generating an estimated compositional yield for hydrocarbon fractions from the hydrocarbon reservoir based on the temperature versus time relationships and the chemical composition of the hydrocarbon sample;generating, using a mass-conserving isotopic fraction (MCIF) simulator that uses ab initio calculations, an estimated isotopic composition of the hydrocarbon fractions based on the estimated compositional yield and ...

SEISMIC PORE-PRESSURE PREDICTION USING PRESTACK SEISMIC INVERSION

A method of predicting pore pressure based on seismic data can include obtaining seismic inversion data based in part on seismic data collected from a formation. The method also includes calculating a pore-pressure transform, wherein the pore-pressure transform comprises parameters derived using measured pore pressure data, upscaled sonic logs, and density logs, wherein the pore-pressure transform comprises an objective function to reduce unphysical variations in predicted pore pressure corresponding to depth. Additionally, the method can include adjusting the pore-pressure transform for sampling bias caused by pore pressure measurements being restricted to a plurality of lithologies by accounting for a difference between upscaled seismic velocities and average sonic velocities within each of the lithologies. Furthermore, the method can include generating pore pressure prediction values based on the pore-pressure transform for the lithologies and the seismic inversion data, and modifying a seismic model based on the generated pore pressure prediction values. 1. A method of predicting pore pressure based on seismic data , comprising:obtaining seismic inversion data based in part on seismic data collected from a formation, wherein the seismic inversion data comprises seismic impedance data;calculating a pore-pressure transform, wherein the pore-pressure transform comprises one or more parameters derived using measured pore pressure data, at least one upscaled sonic log, and at least one density log, wherein the pore-pressure transform comprises an objective function to reduce unphysical variations in predicted pore pressure corresponding to depth;adjusting the pore-pressure transform for sampling bias caused by pore pressure measurements being restricted to a plurality of lithologies by accounting for a difference between upscaled seismic velocities and average sonic velocities within each of the lithologies;generating one or more pore pressure prediction values based ...

Method for predicting cased wellbore characteristics using machine learning

A method for well integrity assessment using machine-trained prediction of physical characteristics related to well integrity across a depth interval of a cased wellbore having one or more casing strings. The method includes collecting scattered X-ray signals from a plurality of X-ray detectors arranged within a well logging tool, learning trained weights to predict wellbore characteristics from the scattered X-ray signals, collecting further scattered X-ray signals from the X-ray detectors, using the trained weights to quantitatively predict the wellbore characteristics from the further X-ray signals, and using the predicted wellbore characteristics to assess well integrity.

QUANTIFICATION OF POLYMER VISCOELASTIC EFFECTS ON SOR REDUCTION USING MODIFIED CAPILLARY

A method of quantifying a viscoelastic effect of a polymer on residual oil saturation (S ) including calculating an extensional capillary number (N) using flux, pore-scale apparent viscosity, and interfacial tension to account for the polymer's viscoelastic forces that are responsible for Sreduction. The polymer is used polymer flooding during enhanced oil recovery. An extensional capillary number is calculated for a plurality of polymer materials, which are then compiled in a database. Also provided is a reservoir simulator for predicting the Sreduction potential of the viscoelastic polymer, which includes a database of calculated extensional capillary numbers for a plurality of polymers. The database includes a curve generated from the calculated extensional capillary numbers for a plurality of polymers properties, flux rates, formation nature, oil viscosities, and rheological behaviors. 2. The method of wherein said polymer is used in polymer flooding is used during enhanced oil recovery (EOR).3. The method of further comprising calculating an extensional capillary number (N) for a plurality of polymer materials.4. The method of further comprising compiling a database of calculated extensional capillary numbers for a plurality of polymers.5. The method of wherein the database includes a curve generated from the calculated extensional capillary numbers for a plurality of polymers properties claim 4 , flux rates claim 4 , formation nature claim 4 , oil viscosities claim 4 , and rheological behaviors.6. The method of wherein the database is configured to predict the Sfor a varying range of polymer concentration claim 4 , brine salinity claim 4 , temperature claim 4 , flux rates claim 4 , permeability claim 4 , oil viscosity claim 4 , porosity claim 4 , a plurality of formations claim 4 , a plurality of displacing.7. The method of wherein the polymer concentration is between 500 ppm to 6000 ppm.8. The method of wherein the brine salinity is between 2000 ppm to 26 ...

EXPERIMENTAL METHOD AND SYSTEM FOR SIMULATING EVOLUTION OF RESERVOIR FRACTURE STRESS FIELD

An experimental method and system for simulating the evolution of reservoir fracture stress field, the experimental method comprises the following steps: (S) preparing horizontal well fracturing model (); (S) applying boundary loads and constraints to the horizontal well fracturing model (); (S) injecting fracturing fluid or fracturing gas into a fracturing wellbore () of the horizontal well fracturing model () after loading for fracturing; in a fracturing stage, a photoelastic fringe image of the horizontal well fracturing model () is obtained by an optical phase shift method; the fracturing stage comprises an initial state before fracturing fluid or fracturing gas is injected and an end state after fracturing is completed. The experimental method and system can effectively simulate the whole process of horizontal well fracturing, and accurately obtain the variation law of reservoir stress field and its influence on crack propagation during horizontal well fracturing. 1. (canceled)2. An experimental method for simulating evolution of a reservoir fracturing stress field , comprising the following steps:preparing a horizontal well fracturing model;applying boundary loads and constraints to the horizontal well fracturing model;injecting fracturing fluid or fracturing gas into a fracturing wellbore of the horizontal well fracturing model after loading for fracturing; wherein in a fracturing stage, a photoelastic fringe image of the horizontal well fracturing model is obtained by an optical phase shift method; the fracturing stage comprises an initial state before fracturing fluid or fracturing gas is injected and an end state after fracturing is completed,wherein that preparing the horizontal well fracturing model comprises the following steps:establishing a digital model of a real reservoir, in which the digital model has a preset wellbore space;making a reservoir 3D model according to the digital model, in which the material of the reservoir 3D model is similar to a ...

Method for evaluating and preventing creep damage to conductivity of hydraulic fracture in gas reservoirs

The present invention discloses a method for evaluating and preventing creep damage to conductivity of hydraulic fracture in gas reservoirs, comprising: (1) selecting a rock sample of target reservoir for creep experiment, and plotting ε-t curve of the rock sample during creep; (2) fitting the fractional Kelvin model with the ε-t curve of the rock sample during creep; (3) calculating the conductivity and permeability of hydraulic fracture considering creep damage; (4) numerically solving the productivity model, calculating the cumulative gas production of the gas well produced up to time t, and calculating the creep damage rate for cumulative production of the gas well; (5) repeating Steps (3) to (4), calculating the creep damage rate for cumulative production for the cases of hydraulic fracture sanding concentration N of 5 kg/m, 7.5 kg/m, 10 kg/m, 12.5 kg/mand 15 kg/mrespectively, plotting the creep damage chart of cumulative production. The present invention belongs to the field of oil and gas field development, in particular to a method for evaluating and preventing creep damage to conductivity of hydraulic fracture in gas reservoirs.Hydraulic fracturing technology has become an irreplaceable development tool in the development of gas reservoirs. After fracturing is completed, hydraulic fractures with high conductivity are formed in the reservoir, and provide efficient flow channels for natural gas seepage. However, it has been found after long-term practice and study that the conductivity of hydraulic fracture will attenuate to varying degrees with the passage of production time, resulting in a gradual decrease in the productivity of fractured wells. In order to reduce the conductivity damage and increase gas well productivity, it is important to study the law and evaluation method of conductivity damage.At present, the method of evaluating the conductivity damage of hydraulic fracture mainly considers the impact of proppant crushing, embedment and deformation. ...

Pumping unit inspection sensor assembly, system and method

A sensor assembly can include a gyroscope, an accelerometer, and a housing assembly containing the gyroscope and the accelerometer. An axis of the gyroscope can be collinear with an axis of the accelerometer. A method of inspecting a well pumping unit can include attaching a sensor assembly to the pumping unit, recording acceleration versus time data, and in response to an amplitude of the acceleration versus time data exceeding a predetermined threshold, transforming the data to acceleration versus frequency data. A method of balancing a well pumping unit can include comparing peaks of acceleration versus rotational orientation data to peaks of acceleration due to circular motion, and adjusting a position of a counterweight, thereby reducing a difference between the peaks of acceleration due to circular motion and the peaks of the acceleration versus rotational orientation data for subsequent operation of the pumping unit.

Fault skeletonization for fault identification in a subterranean environment

A system can receive fault likelihood data about a subterranean environment and apply a binary mask filter using a tuning parameter to convert the fault likelihood data to binary distribution data having a plurality of pixels arranged in a plurality of profiles in at least two directions. The system can perform, for each profile of the plurality of profiles, fault skeletonization on the binary distribution data to form fault skeletonization data with pixels connected that represent part of a fracture. The system can convert the fault skeletonization data to seismic volume data and combine and filter the seismic volume data in the at least two directions to form combined seismic volume data. The system can output the combined seismic volume data as an image for use in detecting objects to plan a wellbore operation.

Improved structural modelling

A method of calculating the likely positions of structures in a region of the earth's crust includes defining the region in the earth's crust; creating a first structural model of the region from seismic data with uncertainties and correlations; creating a second structural model of the region from measurements in a wellbore with uncertainties and correlations; creating a third structural model of the region from measurements in a volume around the wellbore measured from the wellbore with uncertainties and correlations; defining constraining equations for the first, second and third structural models; and using said constraining equations, calculating likely positions of structures in the region, and likely uncertainties and correlations relating to the positions.

ACOUSTIC INTEGRITY IMAGING

Various embodiments include methods and apparatus structured to investigate a structure of multiple strings of pipe in a wellbore and material around the pipes in the wellbore. An array of acoustic receivers can be used to monitor sound energy from the structure and material within and around the structure. The received sound energy can be segregated and coherent signal processing of the received sound energy can be conducted with respect to location. A bond map of the structure and regions around the multiple strings of pipe can be derived from the coherent signal processing. Additional apparatus, systems, and methods can be implemented in a variety of applications. 1. A processor implemented method comprising:monitoring sound energy received in an array of acoustic receivers, the array of acoustic receivers arranged relative to a structure of multiple strings of pipe in a wellbore;segregating frequencies of the sound energy supplying information of the multiple strings of pipe, completion hardware, and/or materials in-between of the structure being sampled by distance and/or frequencies;conducting coherent signal processing of the sound energy with respect to location; andderiving a bond map of the structure and regions around the multiple strings of pipe from completion of the coherent signal processing.2. The processor implemented method of claim 1 , wherein conducting coherent processing of the received sound energy includes generating model beamforming by partitioning the frequencies and magnitude patterns of the received sound energy into locations.3. The processor implemented method of claim 1 , wherein the method includes exciting pipe harmonics of the structure using an acoustic transmitter.4. The processor implemented method of claim 1 ,wherein monitoring sound energy received in the array of acoustic receivers includes monitoring sound energy received in an array of hydrophones,wherein the method includes determining bond indices of different regions of ...

Method and system of evaluating hydrocarbon in heterogeneous formation

Methods and systems for evaluating hydrocarbon in heterogeneous formations are disclosed. The use of three-dimensional simulation of the heterogeneous and porous structure at the nanometer scale of formation facilitates more accurate evaluation of the hydrocarbon reserve and fluid behavior.

Method for Drilling Wellbores Utilizing Drilling Parameters Optimized for Stick-Slip Vibration Conditions

The present disclosure relates generally to the field of drilling operations. More particularly, the present disclosure relates to methods for drilling wells utilizing drilling equipment, more particularly drill string assemblies, and making adjustments to drilling parameters during the drilling operation based on analysis of the drilling data. Included are methods for the selection of modified drilling parameters to mitigate torsional vibration dysfunction.

LEARNING BASED BAYESIAN OPTIMIZATION FOR OPTIMIZING CONTROLLABLE DRILLING PARAMETERS

A method for optimizing real time drilling with learning uses a multi-layer Deep Neural Network (DNN) built from input drilling data. A plurality of drilling parameter features is extracted using the DNN. A linear regression model is built based on the extracted plurality of drilling parameter features. The linear regression model is applied to predict one or more drilling parameters. 1. A method for optimizing drilling of a well , the method comprising steps of:building a multi-layer Deep Neural Network (DNN) from real time input drilling data from the well;extracting a plurality of drilling parameter features from the real time input drilling data using the DNN;building a linear regression model based on the extracted plurality of drilling parameter features;applying the linear regression model to the real time input drilling data to predict one or more drilling parameters for the well; anddrilling the well using the one or more drilling parameters.2. The method of claim 1 , wherein the step of applying the linear regression model further comprises applying a constrained data range to the real time input drilling data to predict the one or more drilling parameters.3. The method of claim 1 , wherein the DNN comprises a Convolution Neural Network (CNN).4. The method of claim 1 , wherein the linear regression model comprises a linear Support Vector Machine (SVM) model.5. The method of claim 4 , wherein the SVM model comprises a SVM model with a Radial Basis Function (RBF) kernel.6. The method of claim 1 , further comprising determining an expected improvement value based on the linear regression model claim 1 , wherein the expected improvement value corresponds to a predicted value of the one or more drilling parameters.7. The method of claim 1 , wherein the one or more drilling parameters comprise one or more of: a Weight On Bit (WOB) claim 1 , a bit Revolutions Per Minute (RPM) claim 1 , flow rate (Q) and Rate of Penetration (ROP).8. The method of claim 6 , further ...

Method of calculating etching profile of acid-etched fracture system considering complex filtration media

The invention introduces a method of calculating etching profile of acid-etched fracture system considering complex filtration media, which mainly considers dynamic filtration caused by natural fractures and acid-etched wormholes in acid fracturing, calculates the above filtration process by a numerical method, and finally calculates acid etching profile of acid-etched fracture system based on acid concentration profile. Calculation equations include fluid pressure in natural fractures, filtration velocity in natural fractures, fracture geometry of hydraulic fractures, fluid pressure in matrix rock, acid concentration profile in natural fractures and hydraulic fractures, acid etching width in hydraulic fractures and natural fractures, and length of acid-etched wormhole, etc. The invention is reliable in principle and efficient in calculation, which is also beneficial to accurately calculating fracture etching profiles of acid fracturing in naturally-fractured reservoirs, improving the accuracy of optimizing acid fracturing treatment parameters, and providing guiding significance for acid fracturing optimization of naturally-fractured carbonate reservoirs. 1. A method of calculating etching profile of an acid-etched fracture system considering complex filtration media , comprising:{'b': '1', 'claim-text': further calculating a total filtration volume of acid to the natural fractures and a matrix rock in a time step,', 'and calculating an average filtration velocity in a fracture propagation grid based on an assumed fluid pressure profile in the matrix rock;, 'step S: calculating a fluid pressure in natural fractures based on natural fracture fluid pressure model,'}{'b': 2', '1, 'step S: calculating a fluid pressure in hydraulic fractures through a hydraulic fracture propagation model, and further calculating a fracture geometry of the hydraulic fractures and a fracture geometry of the natural fractures according to the average filtration velocity in step S;'}{'b': 3 ...

Multi-well fiber optic electromagnetic systems

A method includes activating a first electromagnetic source at a first frequency, acquiring a first set of electromagnetic measurements from a first fiber optic electromagnetic sensor in a first well, wherein the first fiber optic electromagnetic sensor is in electromagnetic communication with the first electromagnetic source. The method also includes acquiring a second set of electromagnetic measurements from a second fiber optic sensor in a second well, wherein the second fiber optic sensor is in electromagnetic communication with the first electromagnetic source. The method also includes determining a formation property based on the first set of electromagnetic measurements and the second set of electromagnetic measurements.

Integrated well completions

A method includes collecting data for a borehole, designing an integrated wellbore isolation plan, the integrated wellbore isolation plan including a drilling plan and a cementing plan for the borehole, and setting zonal isolation parameters for the borehole based on the integrated wellbore isolation plan.

Real-Time Fracture Monitoring, Evaluation And Control

Systems and methods of the present disclosure generally relate to monitoring, evaluating, and controlling fracture geometry during a hydraulic fracturing operation, in real time. A method comprises measuring a signal representing a condition in a wellbore; inputting the signal into a model for estimating a dimension of a dominant fracture; determining the dimension of the dominant fracture; determining a target dimension for the dominant fracture; and minimizing a difference between the dimension of the dominant fracture and the target dimension in real time, by adjusting at least an injection pressure or flow rate of a hydraulic fracturing fluid into the wellbore.

Method and system for predicting formation top depths

A method may include obtaining, by a computer processor, seismic data regarding a geological region of interest. The method may further include obtaining, by the computer processor, well log data from a wellbore within the geological region of interest. The method may further include determining, by the computer processor, a formation top depth using the seismic data, the well log data, a stratigraphic column, and a machine-learning model. The stratigraphic column may describe an order of various formations within the geological region of interest. The machine-learning model may assign a feature among the seismic data and the well log data to a formation among the formations in the stratigraphic column to determine the formation top depth.

SYSTEM AND METHOD FOR CONFIGURING A LOGGING MODULE

A method for configuring a logging module for logging sensors deployment based on a sensing data acquisition objective includes selecting a tool body, selecting at least one type of sensor, and selecting at least one type of roller. The method also includes incorporating the at least one selected type of sensor onto the at least one selected type of roller to provide at least one sensor roller, and mounting the at least one sensor roller into a compressible mounting assembly provided in the tool body to provide the logging module.

Sequential fully implicit well model for reservoir simulation

A subsurface hydrocarbon reservoir with wells is simulated by sequential solution of reservoir and well equations to simulate fluid flow inside the reservoir and well production rates. Sequential solution of reservoir and well equations treats wells as specified bottom hole pressure wells. This avoids solving large matrices resulting from the simultaneous solution of the reservoir and well equations which can be computationally very expensive for large number of unknowns and require special sparse matrix solvers. Such sequential solution involves regular reservoir system solvers complemented by a small matrix for the numerical solution of the well bottom hole pressures.

Sparse Deconvolution And Inversion For Formation Properties

The disclosure relates generally to the inversion of geophysical and/or logging measurements for formation evaluation and monitoring. The disclosure may be related to methods of deconvolution and/or inversion of piecewise formation properties. A method for formation evaluation from a downhole tool may comprise disposing a downhole tool into a wellbore, broadcasting a signal into a formation penetrated by the wellbore, recording the signal from the formation with at least one receiver disposed on the downhole tool, computing an objective function, and determining formation properties by minimizing the objective function.

AI/ML, DISTRIBUTED COMPUTING, AND BLOCKCHAINED BASED RESERVOIR MANAGEMENT PLATFORM

A system for managing well site operations, the system comprising executable partitions, predictive engines, node system stacks, and a blockchain. The predictive engines comprise an Artificial Intelligence (AI) algorithm to generate earth model variables using a physics model, well log data variables, and seismic data variables. The node system stacks are coupled to the blockchain, sensors, and machine controllers. Each node system stack comprises a Robot Operating System (ROS) based middleware controller, with each coupled to each partition, each node system stack, each predictive engine, and an AI process or processes. The blockchain comprises chained blocks of a distributed network. The distributed network comprises a genesis block and a plurality of subsequent blocks, each subsequent block comprising a well site entry and a hash value of a previous well site entry. The well site entry comprises operation control variables. The operation control variables are based on the earth model variables. 1. A system for managing well site operations , the system comprising:at least one predictive engine having at least one selected from a group comprising an artificial intelligence algorithm and a trained artificial intelligence algorithm, the at least one predictive engine generates earth model variables using a physics model and at least one selected from a group comprising well log data variables and seismic data variables;at least one node system stack communicable coupled to the at least one predictive engine, a distributed network, a plurality of sensors, and at least one machine controller; andat least one chained block of a distributed network, the distributed network comprising a genesis block and a plurality of subsequent blocks, each subsequent block comprising a well site entry and a cryptographic hash value of a previous well site entry, wherein the well site entry comprises at least one transacted operation control variable;wherein the at least one transacted ...

METHOD OF DRILLING STRING ASSEMBLY FOR SECONDARY OPENING OF A PRODUCTIVE FORMATION

A method of a drilling string assembly for drilling small-diameter branched channels, including installation of operating elements arranged in a dynamically perturbed section of a loaded part of the drilling string. Moreover, a drilling string assembly, comprising oscillators arranged as coupled oscillators, a bit, a spindle section of a bottom-hole motor, power sections of a screw bottom-hole motor, assemblies of rigid and flexible pipes, as well as a device for regulating the axial load, are installed on a test bench. Bench tests are carried out according to modelled programs of possible emergency or non-emergency operating modes of the assembly, both as a whole and of the separate elements. 1. A method for drill string assembly as a technical dynamic system of connected oscillators for drilling branched channels of small diameter , including an assembly of operating components of various natural frequency positioned in a dynamically disturbed zone of the loaded part of the drill string ,whereina drill string assembly including oscillators positioned as coupled units, a drill bit, a bearing section of the mud motor, power sections of the mud motor, rigid and coiled tubing assemblies with viscoelastic mechanical properties and different natural frequencies, and an axial load control unit, is mounted on a test benchconducting tests following modeled programs of possible emergency and emergency-free operation modes for an assembly as a whole and its individual components,measuring amplitude, vibration speed and vibration acceleration for longitudinal, transverse and torsional vibration are measured for drilling each kind of bed rock, trends for cumulative wave motion are obtained for oscillators moving with collective group speed,analyzing said obtained values are analyzed to determine areas of dynamic stability at the test bench, displacement amplitude, determining vibration speed and vibration acceleration trends for longitudinal, transverse and torsional ...

System and method for reservoired oil production based on calculated composition of natural tracers

A method for production prediction using tracers in an oilfield system is disclosed. The method involves reading, by a computer processor, a set of subsurface field properties characterizing a field system, generating, by the computer processor, a base field model, creating, by the computer processor, a plurality of static models of the field system, running, by the computer processor, a suite of dynamic simulations to produce a plurality of tracer compositions, creating, by the computer processor, a filling envelope function based on the plurality of tracer compositions, calculating, by the computer processor, a production prediction for a measured tracer composition based on the filling envelope function, and executing, by the computer processor, a field operation based on the production prediction, wherein the field operation results in hydrocarbon being extracted from a trap reservoir.

SYSTEM AND METHOD FOR DIAGNOSING BOREHOLE STRUCTURE VARIANCES USING INDEPENDENT COMPONENT ANALYSIS

A method and system to be used in well inspection. An acoustic signal is transmitted from a well inspection tool into a well structure and one or more return signals is detected using at least one receiver. At least one processor is used to generate variable density log (VDL) data that includes multiple waveforms in a time domain from the one or more return signals. A number of independent components to be used based on variances in the VDL data is determined and the multiple waveforms are decomposed into multiple components associated with one or more local structure variances of the well structure using independent component analysis (ICA) and the number of independent components. Characteristics of the well structure is determined based in part on patterns or features associated with one or more independent components from the multiple components. 1. A well inspection method , comprising:transmitting an acoustic signal from a well inspection tool into a well structure;detecting one or more return signals using at least one receiver of the well inspection tool;generating, using at least one processor, variable density log (VDL) data from the one or more return signals, wherein the VDL data comprises a plurality of waveforms in a time domain;determining a number of independent components comprised in the VDL data based at least in part variances identified in the VDL data;decomposing the plurality of waveforms into multiple components using independent component analysis (ICA) and the number of independent components determined in the VDL data, the multiple components associated with one or more local structure variances of the well structure; anddetermining characteristics of the well structure based in part on patterns or features associated with the one or more independent components from the multiple components.2. The method of claim 1 , wherein the characteristics determined of the well structure comprise one or more of: a cement bonding condition claim 1 , a ...

Determining fluid distribution and hydraulic fracture orientation in a geological formation

A system can calculate estimated strain data for a fracture in a geological formation at each of a plurality of selected locations detectable by a strain measurement device. The system can receive real strain data from the strain measurement device for the geological formation. The system can perform a linear inversion to determine a probable distribution of fluid volume and hydraulic fracture orientation in the geological formation based on the estimated strain data and real strain data. The system can determine adjustments for a fracturing operation based on the linear inversion.

GRAPH FRAMEWORK (DATABASE METHODS) TO ANALYZE TRILLION CELL RESERVOIR AND BASIN SIMULATION RESULTS

Systems and methods include a computer-implemented method for generating and using a graph/document structure to store reservoir simulation results. A graph is generated that represents reservoir simulation results of a reservoir simulation performed on a reservoir using a reservoir simulation model. The graph represents a full set of relational data and non-relational data included in the reservoir simulation results. The graph stores graph information and relational data in a graph/document structure. Objects of the reservoir, elements of the reservoir simulation results, and inputs of the reservoir simulation model are represented as vertices in the graph. Relationships between vertices are represented as edges in the graph. An edge is defined by a pair of vertices in the graph. 1. A computer-implemented method , comprising:generating a graph representing reservoir simulation results of a reservoir simulation performed on a reservoir using a reservoir simulation model, wherein the graph represents a full set of relational data and non-relational data included in the reservoir simulation results, and wherein the graph stores graph information and relational data in a graph/document structure;representing, as vertices in the graph, objects of the reservoir, elements of the reservoir simulation results, and inputs of the reservoir simulation model; andrepresenting, as edges in the graph, relationships between vertices, wherein an edge is defined by a pair of vertices in the graph.2. The computer-implemented method of claim 1 , wherein a vertex in the graph can represent an entity selected from a group comprising a reservoir simulation claim 1 , a field claim 1 , an input model claim 1 , a reservoir claim 1 , a surface network claim 1 , a grid claim 1 , a group claim 1 , a well claim 1 , an event claim 1 , a branch claim 1 , one or more devices claim 1 , and a perforation.3. The computer-implemented method of claim 1 , further comprising:importing data into a vertex ...

Self Correcting Prediction Of Entry And Exit Hole Diameter

This disclosure may generally relate to perforating operations and, more particularly, may generally relate to systems and methods for estimating perforated entry and exit hole diameters (EHD) of a casing string. In one embodiment, a method for predicting perforation outcomes may comprise selecting one or more variables for a perforating operation, determining an estimate of a perforating outcome for the perforating operation, and correcting the perforating outcome to obtain a corrected perforating outcome by applying a weighting based on historical perforating data. 1. A method for predicting perforation outcomes , comprising:selecting one or more variables for a perforating operation;determining an estimate of a perforating outcome for the perforating operation; andcorrecting the perforating outcome to obtain a corrected perforating outcome by applying a weighting based on historical perforating data.2. The method of claim 1 , further comprising performing the perforating operation to create one or more perforations in a wellbore and comparing an actual perforation outcome to the corrected perforation outcome.3. The method of claim 1 , further comprising adjusting at least one aspect of the perforating operation based on the perforating outcome claim 1 , and performing the perforating operation to create one or more perforations in a wellbore.4. The method of claim 1 , wherein the variables comprise at least one variable selected from the group consisting of type of ballistic device used in a perforating gun assembly claim 1 , type of charge claim 1 , eccentricity of the perforating gun assembly with a central axis of a wellbore claim 1 , type of wellbore material to be perforated claim 1 , thickness of a casing string claim 1 , and combinations thereof5. The method of claim 1 , wherein the perforating outcome comprises at least one outcome selected from the group consisting of entry hole diameter claim 1 , exit hole diameter claim 1 , depth of penetration claim 1 ...

ANISOTROPY MODEL GUIDED FRACTURE PROPERTIES EXTRACTION FROM VSP DATA

A DAS VSP technique is used to determine the induced fracture height and fracture density of an induced fracture region. The DAS VSP technique obtains pre-hydraulic fracturing DAS VSP survey time-lapse data to establish a baseline reference for the direct acoustic wave travel time. The DAS VSP technique obtains one or more time-lapse data corresponding to the subsequent monitor surveys conducted after each hydraulic fracturing stage along the well. Forward modeling is used to determine a theoretical acoustic wave travel time difference. The forward modeling uses seismic anisotropy to describe the behavior of seismic waves traveling through the induced fracture regions. An inversion scheme is then used to invert for the induced fracture height and the fracture density using the forward modeling. The two extracted induced fracture characteristics may then be used to determine optimal hydraulic fracturing parameters. 1. A method comprising:determining a first travel time difference based on distributed acoustic sensing vertical seismic profile data collected before and after a well stimulation operation in a well with optical fiber;determining a second travel time difference based on forward modeling for the well; anddetermining a fracture height and fracture density with inversion based on a time lapse difference between the first and second travel time differences.2. The method of claim 1 , wherein the first and second travel time differences are P-wave travel time differences.3. The method of further comprising:selecting a range of channels of the well for which the distributed acoustic sensing vertical seismic profile data has been collected,wherein determining the first travel time difference and the second travel time difference is for each of the channels in the selected range;wherein the time lapse difference is calculated for each of the channels; andwherein determining a fracture height and fracture density comprises applying inversion based on the time lapse ...

Determining Hydrocarbon Resource Characteristics Via Mud Logging

Methods (and related apparatus) include obtaining data regarding a measured property. The measured property includes an amount of each of predetermined hydrocarbons in a gas sample extracted from drilling fluid exiting a wellbore having a hydrocarbon resource. An unknown characteristic of an investigated fluid property of the hydrocarbon resource is predicted utilizing the obtained input data and one or more predetermined models each built via statistical classification and regression analysis of a preexisting database containing records. Each record includes known characteristics of fluid properties of a different one of known reservoir fluids. The fluid properties include the investigated fluid property and the measured property. The investigated fluid property includes a fluid type of the hydrocarbon resource, an amount of at least one additional hydrocarbon, gas-oil ratio, or stock tank oil density. 1. A method comprising:obtaining input data regarding at least one measured property, wherein the at least one measured property includes an amount of each of a predetermined plurality of hydrocarbons in a gas sample extracted from drilling fluid after the drilling fluid exits a wellbore, and wherein the wellbore penetrates a subterranean formation comprising a hydrocarbon resource; and the obtained input data; and', 'one or more predetermined models each built via statistical classification and regression analysis of a preexisting database containing a plurality of records, wherein each record comprises known characteristics of a plurality of fluid properties of a different one of a plurality of known reservoir fluids, wherein the plurality of fluid properties comprises the investigated fluid property and the at least one measured property, and wherein the investigated fluid property comprises at least one of a fluid type of the hydrocarbon resource, an amount of at least one additional hydrocarbon, a gas-oil ratio (GOR), or a stock tank oil (STO) density., ' ...

Providing for uncertainty in non-linear inversions of geophysical data

A method of obtaining a model of a sub-surface region, the model comprising a three dimensional matrix of sub-surface material property values. The method comprises providing a first approximation of said model, and performing simulations using the model to generate (i) a reference upgoing energy wave data set d 0 , where the acquisition parameters used in the simulation are a set of known acquisition parameters, and (ii) a plurality of perturbed upgoing energy wave data sets d 0 where the acquisition parameters are obtained by randomly perturbing said set of known acquisition parameters. The method further comprises forming a matrix D, the columns of which are the differences d i −d 0 between the ith perturbed data set and the reference data set, applying an analysis to the matrix D to describe the matrix using a set of vectors, and selecting the most important vectors from said set of vectors to obtain a subset of vectors that describe said matrix D to an approximation. An iterative procedure is performed to improve said first approximation of said model, or a further approximation model, wherein, at each step of the procedure, a model update Δm is determined, the model update being that model update that minimises a measure of the data misfit between said upgoing energy wave data set d rec and a data set simulated using the updated model, said measure using said subset of vectors to account for uncertainty in the upgoing energy wave data set d rec .

A METHOD FOR MULTILAYER HYDRAULIC FRACTURING TREATMENT WITH REAL-TIME ADJUSTING

Methods include designing and performing hydraulic fracturing treatments that utilize tube wave analysis by a combination of a flow rate splitting simulator and a multilayer fracturing (MLF) simulator to optimize treatment design parameters. Methods may also be directed to monitoring, controlling, evaluating and improving hydraulic fracturing treatments in real-time. 2. The method of claim 1 , wherein the model for tube wave propagation comprises a parameter of wellbore reflectivity.3. The method of claim 1 , wherein the fracturing job criterion is the total amount of proppant placed into all fractures.4. The method of claim 1 , wherein a number of stimulated fractures in the multilayer hydraulic fracturing treatment differs from the initial job design.5. The method of claim 1 , wherein the fracturing job criterion is a specific amount of proppant in each fracture.6. (canceled)7. (canceled)8. The method of claim 1 , wherein the model of tube wave propagation determines a number of open fractures in the wellbore and one or more fracture geometry parameters selected from a group: fracture depth claim 1 , fracture length claim 1 , width claim 1 , and height.9. The method of claim 1 , wherein the monitoring of reflected tube waves is performed by a pressure sensor at the wellhead of the wellbore or by one or more distributed pressure sensors in the wellbore.10. (canceled)11. (canceled)12. The method of claim 1 , wherein real-time evaluation is performed through modeling a slurry flow into the wellbore to calculate the flow rate distribution among multiple fractures.13. The method of claim 1 , wherein simulating a fracturing process for the number of open fractures using a multilayer fracturing simulator comprises evaluating one or more fracture geometry parameters.14. The method of claim 1 , wherein adjusting the multilayer fracturing simulator comprises adjusting one or more job parameters selected from a group consisting of: pumping flow rate claim 1 , proppant ...

SYSTEM TO MODEL DISTRIBUTED TORQUE, DRAG AND FRICTION ALONG A STRING

A method and apparatus for performing an operation in a wellbore penetrating the earth's formation. The apparatus includes a string and a first processor. The string is disposed in the wellbore. The first processor a first processor determines, by using a first friction test at a first friction test time, a first friction parameter between a first selected subregion and the wellbore and a second friction parameter between a second selected subregion and the wellbore. 1. A method of performing an operation in a wellbore penetrating the earth's formation , the method comprising:disposing a string in the wellbore;selecting a first subregion of the string and a second subregion of the string;determining, by a first friction test at a first friction test time, a first friction parameter between the first subregion and the wellbore and a second friction parameter between the second subregion and the wellbore; andperforming the operation based on the first friction parameter and the second friction parameter.2. The method of claim 1 , wherein the first friction test comprises moving at least a portion of the string claim 1 , sensing displacement data and dynamic data in conjunction with a movement claim 1 , and determining the first friction parameter and the second friction parameter based on the displacement data and the dynamic data.3. The method of claim 2 , wherein the string comprises a plurality of pipes claim 2 , and wherein the movement of at least the portion of the string comprises an axial movement that is smaller than a length of three pipes.4. The method of claim 1 , wherein the string comprises a plurality of pipes claim 1 , the method further comprising:adding a first pipe to the string or removing the first pipe from the string; anddetermining, by a second friction test at a second friction test time after adding or removing the first pipe to or from the string, a third friction parameter between the first subregion and the wellbore and a fourth friction ...

METHOD AND SYSTEM FOR DETERMINING ENERGY-BASED BRITTLENESS

A method may include determining an energy factor based on scratch test data and ultrasonic wave data regarding a geological region of interest. The method may further include determining an amount of inelastic energy regarding the geological region of interest using triaxial compression data and rock property data. The method may further include determining a tensile strength regarding the geological region of interest using Brazilian test data. The method may further include generating a geomechanical model regarding the geological region of interest using the energy factor and the amount of inelastic energy. The geomechanical model may include various brittleness values for the geological region of interest. The method may further include determining an injection fluid pressure to induce a hydraulic fracture at a predetermined location in the geological region of interest using the geomechanical model, the tensile strength, and fracture plane roughness data. 1. A method , comprising:determining, by an computer processor, an energy factor based on scratch test data and ultrasonic wave data regarding a geological region of interest;determining, by the computer processor, an amount of inelastic energy regarding the geological region of interest using triaxial compression data and rock property data;determining, by the computer processor, one or more tensile strengths regarding the geological region of interest using Brazilian test data;generating, by the computer processor, a geomechanical model regarding the geological region of interest using the energy factor and the amount of inelastic energy, wherein the geomechanical model comprises a plurality of brittleness values for the geological region of interest; anddetermining, by the computer processor, an injection fluid pressure to induce a hydraulic fracture at a predetermined location in the geological region of interest using the geomechanical model, the one or more tensile strengths, and fracture plane ...

Systems and Methods for Developing Horizontal Hydrocarbon Wells

Provided are techniques for generating and validating facies logs for a horizontal wellbore, including: obtaining facies data for a subsurface formation, including vertical wellbore core data and wireline log data; determining (based on the facies data) a depositional model; determining (based on the facies data) a facies model of a horizontal portion of a wellbore in an target interval of the formation, including a predicted facies log; determining (based on the depositional model) a facies thickness mapping; determining for different locations within the formation (based on a comparison of the predicted facies log and the facies thickness mapping), a discrepancy between the facies of the predicted facies log and the facies thickness mapping for the location; and for locations of a discrepancy, modifying the predicted facies for the location based on the facies indicated for location by the facies thickness mapping, to generate a modified predicted facies log. 1. A method of developing a hydrocarbon well , the method comprising: vertical wellbore core data obtained by way of core samples extracted from vertical portions of wellbores of wells that extend into the subsurface formation, the vertical wellbore core data comprising characteristics of the core samples measured in a core laboratory after extraction of the core; and', vertical wireline log data that corresponds to downhole logging of vertical portions of the wellbores of the wells that extend into the subsurface formation; and', 'horizontal wireline log data that corresponds to downhole logging of horizontal portions of the wellbores of the wells that extend into a target interval of the subsurface formation;, 'wireline log data obtained by way of downhole logging of wellbores of wells that extend into the subsurface formation, the wireline log data comprising characteristics of rock of the subsurface formation measured in-situ by way of a downhole logging tool, the wireline log data comprising], 'obtaining ...

SYSTEMS AND METHODS TO IMPROVE DIRECTIONAL DRILLING

The disclosed embodiments include systems and methods to improve down-hole drilling. In one embodiment, a method to improve downhole drilling includes receiving a well plan, where the well plan is indicative of a well path to form a borehole of a hydrocarbon well is provided. The method also includes receiving measurements indicative of a previously-drilled section of the borehole. The method further includes generating, based on the measurements, a trajectory of the borehole, where the trajectory is a function of a depth. The method further includes providing the trajectory of the borehole to a Model Predictive Controller. The method further includes steering a tool towards the well path based on an output of the Model Predictive Controller. 1. A method to improve downhole drilling , the method comprising:receiving a well plan, the well plan being indicative of a well path to form a borehole of a hydrocarbon well;receiving measurements indicative of a previously-drilled section of the borehole;generating, based on the measurements, a trajectory of the borehole, wherein the trajectory is a function of a depth;providing the trajectory of the borehole to a Model Predictive Controller; andsteering a tool towards the well path based on an output of the Model Predictive Controller.2. The method of claim 1 , further comprising:calculating a cost function in the model predictive controller, the cost function having a first component being a deviation between the trajectory of the borehole and drill path, anddetermining a steering action that minimizes the cost function,wherein steering the tool towards the well path comprises instructing the tool to perform the steering action obtained from a minimization of the cost function.3. The method of claim 2 , wherein the cost function comprises at least one additional component claim 2 , the at least one additional component comprising at least one of a tortuosity of the trajectory of the borehole claim 2 , a rate of penetration ...

Shaped charge effect measurement

A method includes determining a perforation tunnel geometry of a perforation tunnel in a solid sample, the perforation tunnel created by activating a shaped charge in proximity to the solid sample. The method also includes performing a first flow test on the solid sample and creating an analog aperture having an aperture geometry in a solid sample analog of the solid sample, wherein the aperture geometry and the perforation tunnel geometry satisfies a similarity threshold. The method also includes performing a second flow test on the solid sample analog and determining a shaped charge effect based on a comparison between a second flow test result and a first flow test result.

METHOD AND SYSTEM FOR PROCESSING WELL LOG DATA FROM MULTIPLE WELLS USING MACHINE LEARNING

A method may include obtaining well log data regarding a geological region of interest. The well log data may correspond to logging-while-drilling (LWD) measurements or measurement-while-drilling (MWD) measurements acquired from various wellbores. The method may further include generating image data regarding the geological region of interest using the well log data and a recurrent neural network. The method may further include determining a drilling parameter for a wellbore among the wellbores in real-time using the image data. The drilling parameter may be determined while the well log data is being acquired in the wellbore. The method may further include transmitting, based on the drilling parameter, a command to a drilling system coupled to the wellbore. 1. A method , comprising:obtaining, by a computer processor, well log data regarding a geological region of interest, wherein the well log data corresponds to logging-while-drilling (LWD) measurements or measurement-while-drilling (MWD) measurements acquired from a plurality of wellbores;generating, by the computer processor, image data regarding the geological region of interest using the well log data and a first recurrent neural network;determining, by the computer processor, one or more drilling parameters for a wellbore among the plurality of wellbores in real-time using the image data,wherein the one or more drilling parameters are determined while the well log data is being acquired in the wellbore; andtransmitting, by the computer processor and based on the one or more drilling parameters, a command to a drilling system coupled to the wellbore.2. The method of claim 1 ,wherein the first recurrent neural network comprises a plurality of long short-term memory (LSTM) cells,wherein a respective LSTM cell among the plurality of LSTM cells generates a respective output class signal, andwherein the respective LSTM cell obtains a previous output class signal and a cell state signal from a previous LSTM cell ...

USING PRE-FRACTURING HYDRAULIC CONDUCTIVITY MEASUREMENTS TO AVOID FRACTURE TREATMENT PROBLEMS

A method for predicting fracture treatment performance includes inducing tube waves in a well drilled through a formation to be fracture treated. A polarity of reflected tube waves in the well is determined, and using the reflected tube waves, hydraulic conductivity of at least one zone in the well hydraulically connected to the formation is estimated. The estimated hydraulic conductivity is compared to a selected threshold. The selected threshold is based on pumping parameters and pumping pressure behavior of at least one pumped hydraulic fracture treatment. A warning signal is generated when the hydraulic conductivity is below the selected threshold and/or the determined polarity indicates a closed boundary condition so that the treatment may be adjusted to avoid screenouts and other operational and treatment issues. 1. A method for predicting fracture treatment performance , comprising:inducing tube waves in a well drilled through a formation to be fracture treated during or after opening a wellbore fluid connection to the formation;determining a polarity of reflected tube waves in the well and using the reflected tube waves to estimate hydraulic conductivity of at least one zone in the well hydraulically connected to the formation;comparing the estimated hydraulic conductivity to a selected threshold, the selected threshold based on pumping parameters of at least one pumped hydraulic fracture treatment; andgenerating a warning signal when the hydraulic conductivity is below the selected threshold and/or the determined polarity indicates a closed boundary condition.2. The method of wherein the at least one pumped hydraulic fracture treatment is made in a treatment stage in the well already having a fracture treatment pumped into the treatment stage.3. The method of wherein the selected threshold is estimated using measurements from at least one pumped hydraulic fracture treatment made in a different well.4. The method of wherein the selected threshold is obtained ...

BOREHOLE LOCALIZATION RELATIVE TO OBJECTS AND SUBTERRANEAN FORMATIONS

This disclosure presents methods and processes to estimate a position parameter, an orientation parameter, a dip parameter, and a diameter parameter of an object or subterranean formation change proximate an active borehole. The object or formation can be an adjacent borehole. The parameters can be utilized by a geo-steering system or a well site job plan system to reduce an uncertainty surrounding or looking ahead of the active borehole to avoid a collision with the object or formation, to intercept the object or formation, or to place the active borehole in a more advantageous position. The parameters can be derived from collected component resistivity data that has been reconstructed utilizing a three-dimensional inversion algorithm. In some aspects, low resistivity data can be extracted to improve the estimating of the parameters. In some aspects, the process can be implemented in a downhole tool, in a surface system, or a combination thereof. 1. A method , comprising:collecting component resistivity data utilizing a resistivity tool located downhole of an active borehole of a well site;reconstructing the component resistivity data to generate reconstructed resistivity data utilizing a three-dimensional (3D) inversion algorithm, wherein the reconstructed resistivity data represents information on part of an object or of a subterranean formation change in a proximate subterranean formation; andcomputing generated results utilizing the reconstructed resistivity data.2. The method as recited in claim 1 , wherein the object or the subterranean formation change is located at one or more of a radial position or a look ahead area respective to the active borehole and further comprising:communicating the generated results to one or more of a user, a well site controller, or a geo-steering system.3. The method as recited in claim 1 , further comprising:receiving input parameters, wherein the input parameters are utilized by the collecting and reconstructing, and the ...

METHOD AND TEST SYSTEM FOR DETERMINING SAND PUMPING PARAMETERS BASED ON WIDTH DISTRIBUTION OF FRACTURE

A method for determining sand pumping parameters based on width distribution of fracture, including: acquire basic parameters of a target reservoir, simulate a propagation of the fracture, and obtain a propagation pattern and width distribution of the fracture; determine a maximum proppant particle size for entering the fracture at all width levels according to statistical results of the width distribution of the fracture; determine a multi-size combination of proppants according to a mapping table for particle size vs mesh of proppants, and determine an initial ratio of the proppant with each particle size; conduct a numerical simulation of proppant transportation in the fracture to determine a retention ratio of the proppants with each particle size; correct the initial ratio of the proppants with each particle size; calculate an amount of the proppants with each particle size according to the final ratio and the sand pumping intensity and fracturing interval length. 1. A method for determining sand pumping parameters based on a width distribution of a fracture , comprising the following steps:Step 1: using a plurality of sensors to acquire basic parameters of a target reservoir, using a test system to simulate a propagation of the fracture, and using the test system to obtain a propagation pattern and the width distribution of the fracture;Step 2: using the test system to determine a maximum proppant particle size for entering the fracture at all width levels according to statistical results of the width distribution of the fracture;Step 3: using the test system to determine a multi-size combination of proppants according to a mapping table for particle size vs mesh of the proppants, and determining an initial ratio of the proppants with each particle size based on a ratio of each fracture width;Step 4: using the test system to conduct a numerical simulation of proppant transportation in the fracture to determine a retention ratio of the proppants with each ...

METHODS AND SYSTEMS FOR GAS CONDENSATE WELL PERFORMANCE PREDICTION

A method may include determining, during a first time step within an iterative simulation process, various pseudo-pressure values based on model data. The method may include determining, during the first time step, a first set of skin factor values for the wellbore radial grid portions using the pseudo-pressure values. The method may include simulating, during the first time step, a first well production rate for a well within a reservoir region of interest using the first set of skin factor values and a first pressure distribution for the reservoir region of interest. The method may include simulating, during a second time step within the iterative simulation process, a second well production rate for the well using a second set of skin factor values and a second pressure distribution for the reservoir region of interest. 1. A method , comprising:obtaining, by a computer processor, a coarse grid model comprising a plurality of wellbore radial grid portions and model data for a reservoir region of interest;determining, by the computer processor and during a first time step within an iterative simulation process, a plurality of pseudo-pressure values based on the model data;determining, by the computer processor and during the first time step, a first plurality of skin factor values for the plurality of wellbore radial grid portions using the plurality of pseudo-pressure values, wherein the first plurality of skin factor values correspond to gas mobility within the reservoir region of interest;simulating, by the computer processor and during the first time step, a first well production rate for a well within the reservoir region of interest using the first plurality of skin factor values and a first pressure distribution for the reservoir region of interest; andsimulating, by the computer processor and during a second time step within the iterative simulation process, a second well production rate for the well using a second plurality of skin factor values and a ...

RAPID REGION WIDE PRODUCTION FORECASTING

A method for rapid region wide production forecasting includes identifying base data of a well in a plurality of wells of a region; selecting, using the base data and from a set of a models comprising a rich machine learning model, a location based machine learning model, and a decline curve model, a well model; and generating, based on the selecting, a forecasted production of the well using the base data and the well model. The method further includes aggregating a plurality of forecasted productions of the plurality of wells, the plurality of forecasted productions including the forecasted production, to generate a region forecast using the rich machine learning model, the location based machine learning model, and the decline curve model; and presenting the region forecast. 1. A method comprising:identifying base data of a well in a plurality of wells of a region;selecting, using the base data and from a set of a models comprising a rich machine learning model, a location based machine learning model, and a decline curve model, a well model;generating, based on the selecting, a forecasted production of the well using the base data and the well model;aggregating a plurality of forecasted productions of the plurality of wells, the plurality of forecasted productions including the forecasted production, to generate a region forecast using the rich machine learning model, the location based machine learning model, and the decline curve model; andpresenting the region forecast.2. The method of claim 1 , further comprising: 'when the base data includes production data for the rich machine learning model and an end date of the base data is before a threshold number of months of production, using the rich machine learning model to generate the forecasted production to the sooner of the threshold number of months of production and a forecast date, and then using the decline curve model to generate the forecasted production from the threshold number of months of ...

INDUCED DRILLING METHOD FOR INERTIA CONSTRAINED IMPLICATED MOTION AND INERTIAL CONSTRAINT INDUCED DRILLING DEVICE

The invention discloses an induced drilling method for inertial constraint implicated motion, which is characterized by comprising a motion step of separating weight on bit and torque. The induced drilling method of inertial constraint implicating motion comprises the following steps: step 1, model selection of induced drilling; step 2, potential energy storage of induced drilling, wherein step 2 includes: I, uniform cutting induced drilling under a steady condition; II, distribution of induced drilling shock wave propagation under a transient condition; III, potential energy release of torsion spring in induced drilling under the transient condition; IV, constrained buffer for induced drilling under transient conditions; and V, potential energy compensation for induced drilling under transient conditions. The invention also discloses an inertia constraint induced drilling device accompanying the PDC bit. 1. A induced drilling method for an inertia constrained implicated motion , characterized by comprising: the determined model for the induced drilling can connect an inertia gear ring with a planet carrier via a torsion spring;', {'sup': '2', 'the determined parameters of the model for the induced drilling are: the transmission ratio m between the drill string input and the drill bit output in the drilling device induced by the inertia constraint of the PDC bit is more than or equal to m≥1.0, and the rotational inertia I of the inertia gear ring is equal to 0.25-5.4 kgm], 'Step 1, model selection for the induced drilling {'sub': 0', '0', '0, 'starting the drilling system to enable the drill string to start storing potential energy in the torsion spring at the rotation speed ω; when the torque of the drill bit reaches the rock breaking torque T, the inertia gear ring will twist the torsion spring by θ radian relative to the drill bit, and reverse potential energy −mtθ is stored in the torsion spring according to the transmission method of the planetary gear reducer ...

ACID STIMULATION METHODS

Matrix acidizing treatment are designed and performed in a manner that takes into account radial acid flow into the formation. Subterranean well characteristics are determined (e.g., mineralogical and petrophysical characteristics). One of more candidate acids is selected. A linear pore volume of acid to breakthrough (PVBT) curve is generated for each candidate acid. The linear PVBT curves are modified to account for radial acid flow. The optimal acid is selected by considering wormhole development and cost. An initial acid pumping schedule is generated for the formation to be acidized, including the optimal acid, the treatment volume and the injection rate. Computer software is used to consider the subterranean well characteristics, simulate the initial acid pumping schedule and compare results with the radial PVBT curve. The initial schedule is modified until the results are consistent with the radial PVBT curve. An acidizing treatment is then performed. 1. A method for acidizing a formation in a subterranean well , comprising:determining subterranean well characteristics, the characteristics comprising a subterranean well geometry, and mineralogical and petrophysical characteristics of the formation to be acidized;selecting one or more candidate acids, and generating a linear pore volume of acid to breakthrough (PVBT) curve for each candidate acid;modifying the linear PVBT curve to account for radial acid flow through the formation;selecting an optimal acid by considering at least an efficiency of wormhole development and cost;generating an initial acid pumping schedule for the formation to be acidized, wherein the schedule comprises the optimal acid, treatment volume and injection rate;using computer software to consider the subterranean well characteristics, simulate the initial acid pumping schedule in the subterranean well and compare results with the radial PVBT curve;modifying the initial acid pumping schedule such that the results are consistent with the ...

Grid Modification During Simulated Fracture Propagation

Geologic modeling methods and systems disclosed herein employ an improved simulation gridding technique that optimizes simulation efficiency by balancing the computational burdens associated with remeshing against the performance benefits of doing so. One method embodiment includes: (a) obtaining a geologic model representing a subsurface region as a mesh of cells, at least some of the cells in the mesh having one or more interfaces representing boundaries of subsurface structures including at least one fracture; (b) determining a fracture extension to the at least one fracture; (c) evaluating whether the fracture extension is collocated with, or is proximate to, an existing cell interface, and using the existing cell interface if appropriate or creating a new cell interface if not; and (d) outputting the updated version of the geologic model.

SYSTEMS AND METHODS FOR ESTIMATING HYDRAULIC FRACTURE SURFACE AREA

Systems and methods for determining fluid leak-off rate and estimating hydraulic fracture surface area originated from a wellbore, are provided. Method includes connecting a pressure gauge to wellbore to monitor pressure during and after hydraulic fracturing operations. Method includes identifying a fracture pressure, where identified fracture pressure is larger than a formation pore pressure and smaller than a fracture propagation pressure. Method also includes regulating injection rate of an injection fluid to a created hydraulic fracture to maintain constant fracture pressure, such that created hydraulic fracture maintains its current dimensions and injection rate of injection fluid into created hydraulic fracture equals total fluid leak-off rate from created hydraulic fracture, where constant fracture pressure equals identified fracture pressure. Method further includes utilizing fluid leak-off model to estimate hydraulic fracture surface area of created hydraulic fracture, where fluid leak-off model provides relationship between total fluid leak-off rate and hydraulic fracture surface area. 1. A method for determining total fluid leak-off rate from a created hydraulic fracture that originated from a wellbore , the method comprising:monitoring pressure in the wellbore after creation and extension of the created hydraulic fracture; andregulating injection rate of an injection fluid to the created hydraulic fracture to maintain a constant fracture pressure for a continuous period of time, such that the created hydraulic fracture maintains its current dimensions and the injection rate of the injection fluid into the created hydraulic fracture equals the total fluid leak-off rate from the created hydraulic fracture, wherein the constant fracture pressure is larger than a formation pore pressure and smaller than a fracture propagation pressure.2. The method as claimed in further comprising estimating the formation pore pressure and the fracture propagation pressure.3 ...

Method for establishing chart for designing mechanical properties of cement stones in large-scale fracturing oil well

A method for establishing a chart for designing mechanical properties of cement stones in a large-scale fracturing oil well is provided, including steps of: establishing a stress distribution model of a cement sheath based on a theory of elasticity and thick-walled cylinder; establishing a cement sheath integrity prediction model based on the cement sheath failure criterion and the stress increment distribution state of the cement sheath; establishing a cement sheath integrity control method based on the cement sheath stress analysis model and the cement sheath integrity prediction model; establishing a functional relationship between cement stone mechanical parameters and strength parameters based on the cement sheath integrity control method; and establishing a cement stone performance index control chart based on the functional relationship between the cement stone mechanical parameters and strength parameters. 1. A method for establishing a chart for designing mechanical properties of cement stones in a large-scale fracturing oil well , comprising steps of:{'b': '1', 'S: establishing a stress distribution model of a cement sheath based on a theory of elasticity and thick-walled cylinder;'}{'b': '2', 'S: establishing a cement sheath integrity prediction model based on a cement sheath failure criterion and a stress increment distribution state of the cement sheath;'}{'b': '3', 'S: establishing a cement sheath integrity control method based on a cement sheath stress analysis model and the cement sheath integrity prediction model;'}{'b': '4', 'S: establishing a functional relationship between cement stone mechanical parameters and strength parameters based on the cement sheath integrity control method; and'}{'b': '5', 'S: establishing a cement stone performance index control chart based on the functional relationship between the cement stone mechanical parameters and strength parameters.'}21. The method for establishing the chart for designing mechanical properties ...

Automatic rheological parameter measuring system and use method for flowing drilling fluid with high temperature and high-pressure

The invention relates to an automatic measuring system and a use method thereof for drilling fluid parameters measurement under high temperature and high-pressure conditions. The system is composed of six parts: i. mud container, used both for test drilling fluid preparation and the tested samples collection; ii. heat jacket, which is arranged on the outer surface of the fluid tank and used to keep the drilling fluid in the tank warm by heating; iii. heat exchanger, receive the test drilling fluid from the tank and heat it to simulate the practical conditions; iv. plunger pump, which is used to pump the test drilling fluid to the flowing test device; v. moveable test device, used to simulate the flowing states of drilling fluid in the borehole annulus and drilling string, and also measure the pressure and flow rate of drilling fluid in the inlet and outlet of the test device; vi. control module, which can automatically measure rheological parameters and obtain the best rheological mode of the drilling fluid in the borehole annulus and drilling string based on the inversion of instantaneous pressure and flow rate. With the invention system, the accuracy of rheological parameters measurement can be significantly improved.

METHOD FOR DETERMINING HYDROCARBON PRODUCTION OF A RESERVOIR

A method for determining hydrocarbon production of a reservoir includes modeling the reservoir with a gridded model having a coarse partition and a fine partition. A first matrix is determined based on a Jacobian matrix function of the gridded model. A first projector matrix is determined as a concatenation of relevant generalized eigenvectors of a first square matrix and a second square matrix derived from the first matrix. A submatrix is extracted from the first projector matrix, and a projector matrix is determined based on a concatenation of vectors derived from relevant generalized eigenvectors of a third square matrix and a fourth square matrix derived from the submatrix. A preconditioner operator is determined based on the projector matrix, and hydrocarbon production is determined for the reservoir based on the preconditioner operator. 1. A computer-implemented method for determining hydrocarbon production of a reservoir , wherein the method comprises: coarse partition, said coarse partition having coarse subdomains,', 'a fine partition, said fine partition having fine subdomains, each coarse subdomain being composed of a subset of fine subdomains;, 'modeling the reservoir with a gridded model comprising a plurality of cells, said gridded model havingdetermining a first matrix based on a Jacobian matrix function of the gridded model;wherein each fine subdomain has a respective first order value, said first order value being function of an index of a line in a subset of consecutive lines of the first matrix corresponding to said fine subdomain,wherein each coarse subdomain has a respective second order value, said second order value being function of an index of a line in a subset of consecutive lines of the first matrix corresponding to said coarse subdomain;wherein the method further comprises:splitting the first matrix into subsets of consecutive lines, each subset of consecutive lines corresponding to a respective fine subdomain, each subset of consecutive ...

3D RESERVOIR MODELLING BASED ON DYNAMIC PRODUCTION LOGGING TECHNOLOGIES

Reservoir modelling is achieved via the tracing of inflow profiles of horizontal wells in an oilfield. The tracing is implemented via quantum dot markers released into the wells at specific times. The markers are released out of containers or other release-type tools at different intervals of interest. Each set of markers consists of a specific type of quantum dot that produces light of a specific wavelength when illuminated by ultraviolet (UV) light. The markers contain a hydrophilic material that is attracted to water or an oleophilic material that is attracted to oil. When the markers are flushed out with fluid from the well, the number of markers with a specific identifier associated with a specific interval is detected in the fluid, via the perceived wavelength(s), which, in turn, determine how much water versus oil is produced by each specific interval assessed. Recommendations are provided based on the assessments. 1. A method for analyzing and improving oilfield production , comprising:introducing a plurality of microspheres into an oil well during a given fracturing event, a portion of said plurality of microspheres comprising hydrophilic microspheres, another portion of said plurality of microspheres comprising oleophilic microspheres, wherein all microspheres carry within them an identifiable plurality of quantum dots,periodically collecting, at collection points, fluid of the oilfield, said fluid comprising oil, water, and said microspheres,determining, based on identifiers of said quantum dots within said collected fluid, one or more quantities of microspheres,determining, based on said one or more quantities of microspheres, one or more inflow profiles of said oilfield,determining, based on said one or more inflow profiles, a water leak location of said oilfield,providing, based on said one or more inflow profiles and/or any determined water leak locations, one or more recommendations for improving the oilfield production.2. The method of claim 1 , ...

WATERFLOOD FRONT IMAGING USING SEGMENTALLY INSULATED WELL LINERS AS ON-DEMAND ELECTRODES

A method for monitoring waterfront movement in a subsurface formation involves performing forward modeling of at least one deep electromagnetic survey of the waterfront movement, and determining locations for installing an electrically insulating spacer between well liners to form an on-demand electromagnetic source electrode. Based on the forward modeling, repeat survey time intervals are predicted. The method involves, during well completion, installing the electrically insulating spacer between the well liners in a reservoir to form at least one on-demand electromagnetic source electrode, and installing the electrically insulating spacer between the plurality of well liners in a reservoir to form an on-demand electromagnetic receiver electrode. A waterfront survey is performed by conveying a production logging tool into a well that temporarily converts the well liners into an on-demand electromagnetic source electrode and an on-demand receiver electrode, and inverse modeling of the waterfront survey is performed to produce a water saturation image. 1. A method for monitoring waterfront movement in a subsurface formation , the method comprising:performing forward modeling of at least one deep electromagnetic survey of the waterfront movement;determining, based on the forward modeling, locations for installing at least one electrically insulating spacer between a plurality of well liners to form at least one on-demand electromagnetic source electrode;determining, based on the forward modeling, locations for installing at least one electrically insulating spacer between a plurality of well liners to form at least one on-demand electromagnetic receiver electrode;predicting, based on the forward modeling, repeat survey time intervals;during well completion, installing the at least one electrically insulating spacer between the plurality of well liners in a reservoir to form at least one on-demand electromagnetic source electrode;during well completion, installing the ...

Active control method and control device for wellbore pressure in the open-cycle drilling of marine natural gas hydrates

An active control method and control device for wellbore pressure in the open-cycle drilling of marine natural gas hydrates comprises following steps: (1) optimized design of drilling parameter; (2) carry out open-cycle drilling according to the designed drilling parameters; (3) utilize the APWD to monitor the bottom-hole temperature and the bottom-hole pressure in real time for real-time correction of the wellbore annulus temperature and pressure calculation models; determine whether a hydrate decomposition has occurred in the annulus and then infer whether a shallow gas intrusion has occurred in the bottom hole; (4) Intelligent active control: control and adjust the mixed density of drilling fluid, the injection displacement of drilling fluid as well as the injection temperature of drilling fluid and the pump pressure in wellhead automatically during the well killing based on the real-time treatment results of the computer terminal for the signal fluctuations detected by the APWD. 1. An active control method for wellbore pressure in the open-cycle drilling of marine natural gas hydrates , which comprises steps as follows:(1) optimized design of drilling parameters: design the drilling fluid displacement, pump pressure in wellhead, and injection temperature of drilling fluid during the drilling through calculations based on the data of the marine NGH reservoirs to be drilled;(2) open-cycle drilling: carry out open-cycle drilling according to the drilling parameters designed in step (1) by injecting seawater into the drill pipe as drilling fluid to carry the cuttings from the bottom hole and discharge them out of the subsea wellhead through the annulus between the drill pipe and the casing pipe;(3) real-time monitoring of drilling: utilize the APWD to monitor the bottom-hole temperature and the bottom-hole pressure in real time for real-time correction of the wellbore annulus temperature and wellbore annulus pressure calculation models; determine whether a hydrate ...

A method and apparatus for verifying a well model

The present invention relates to a method for verifying a well model, comprising the steps of receiving stored well data of an existing well, forming a model based on the received well data, submerging a tool for performing a work task into the existing well, wherein the tool is arranged to sense present well characteristics when submerged, receiving tool data corresponding to the presently sensed well characteristics from the tool, said tool data representing downhole properties relevant to downhole operation and performance of the tool, and performing a confirmation check by comparing the well data of the model with the tool data. Furthermore, the present invention relates to a well model verifying apparatus, to a well model verifying system and to a computer readable storage medium.

DETERMINING A CHARACTERISTIC ASSOCIATED WITH A RESERVOIR

Techniques for determining a reservoir characteristic include determining, with an analytical solution, a change to at least one control point of a boundary of a control volume defined in a subterranean formation, the change to the at least one control point caused by a hydraulic fracture formed in or adjacent the subterranean formation; determining, with a numerical solution, a fluid pressure change of the control volume based on the change to the at least one control point; and determining, with a mechanical model based on the analytical solution and the numerical solution, at least one reservoir characteristic based at least in part on the determined fluid pressure change of the control volume.

DYNAMIC FRACTURE WIDTH CALCULATION METHOD FOR DRILLING FLUID LOSS IN FRACTURED FORMATION

The invention relates to a dynamic fracture width calculation method for drilling fluid loss in a fractured formation, which belongs to the field of loss control of drilling and well completion engineering, and includes the following steps: selecting a model according to seismic data and fracture development characteristics and calculating a static hydraulic width of a formation fracture; substituting the static hydraulic width of the formation fracture into a deformation formula of a fracture hydraulic width, to obtain a dynamic hydraulic width of a wellbore fracture; converting the dynamic hydraulic width of the wellbore fracture into an average mechanical width of the wellbore fracture, according to a conversion relational formula of a mechanical width; and solving a mechanical width distribution range of the fracture according to a standard deviation of a mechanical width distribution of a natural fracture.

PREDICTIVE MODELS AND MULTI-OBJECTIVE CONSTRAINT OPTIMIZATION ALGORITHM TO OPTIMIZE DRILLING PARAMETERS OF A WELLBORE

A computer-readable medium performs a method for performing a drilling operation in a formation. A plurality of predictive models are determined. Each predictive model of the plurality of predictive models is determined for an interval in the downhole formation, wherein each predictive model of the plurality of predictive models relates one or more drilling parameters of the drilling operation to a plurality of objectives for the drilling operation. A plurality of target objectives is defined. A plurality of outcomes is determined for each of the predictive models of the plurality of predictive models and the plurality of target objectives. An optimization is performed to select an outcome from the plurality of outcomes. The drilling operation is performed using the selected outcome to achieve the plurality of target objectives.

Solder fatigue modeling

The present disclosure models the testing of oilfield electronic equipment that operate in high temperature downhole environments (possibly with large vibrational loading) in order to quantify the damage to the electronic equipment over its expected operational lifetime. The simulated downhole environment is complex and includes coupled random vibration and thermal cycling followed by repeated shock at high temperature. In embodiments, the proposed methods and system measure non-linear damage accumulation of the electronic equipment in this simulated downhole environment.

MICRO-ROTATING DRILLING METHOD IN DIRECTIONAL DRILLING, COMPUTER DEVICE AND READABLE STORAGE MEDIUM

The invention discloses a micro-rotating drilling method in directional drilling, a computer device and a readable storage medium. Including: acquiring rotation speed and torque and on-site drilling information; taking the rotation speed and the torque as a micro-rotating drilling state learning sample, taking the on-site drilling information as a second learning sample, inputting to a neural network control model for training, outputting a micro-rotating drilling algorithm for controlling the top drive; controlling the top drive with the micro-rotating drilling algorithm to achieve the micro-rotation operation. In the invention, an maximum torque and an maximum speed of the top drive can be continuously controlled during the operations such that the drill string can drive the drill tool to drill forward at a preset speed, static frictional resistance exerted on the drill string can be better eliminated. 1. A micro-rotating drilling method in directional drilling , comprising:acquiring rotation speed data and torque data of a top drive;acquiring on-site drilling information;taking the rotation speed data and the torque data of the top drive as a first learning sample, taking the on-site drilling information as a second learning sample, inputting the first learning sample and the second learning sample to a neural network control model for training, and outputting a micro-rotating drilling algorithm for controlling the top drive; wherein the first learning sample is a micro-rotating drilling state learning sample, and the micro-rotating drilling state means that a torque and a rotation speed of the top drive are within a preset range; andcontrolling the top drive with the micro-rotating drilling algorithm to achieve the micro-rotation operation.2. The micro-rotating drilling method for the directional well according to claim 1 , wherein said controlling the top drive with the micro-rotating drilling algorithm to achieve the micro-rotation operation comprises: ...

CIVIL ENGINEERING WORK DATA PROCESSING DEVICE, CIVIL ENGINEERING WORK DATA PROCESSING METHOD, AND CIVIL ENGINEERING WORK DATA PROCESSING PROGRAM

A technique enables easy quantitative evaluation for drilling operations. A civil engineering work data processing device includes a positioning data receiving unit, a three-dimensional model estimating unit, and a drilled depth calculator. The positioning data receiving unit receives positioning data obtained by performing positioning using laser light, on a drilling rod. The three-dimensional model estimating unit estimates a three-dimensional model of the drilling rod, on the basis of the positioning data. The drilled depth calculator calculates a depth of a hole generated in a civil engineering work target by the drilling rod, on the basis of the estimated three-dimensional model. 1. A civil engineering work data processing device comprising a processor or circuitry , the processor or circuitry configured to:receive positioning data obtained by performing positioning using laser light, on a member to be pushed into a civil engineering work target;estimate a three-dimensional model of the member on a basis of the positioning data; andcalculate a displacement of the member relative to the civil engineering work target, on a basis of the estimated three-dimensional model.2. The civil engineering work data processing device according to claim 1 , wherein the member to be pushed into the civil engineering work target is a longitudinal member for drilling claim 1 , and a depth of a hole that is generated in the civil engineering work target by the longitudinal member is calculated by calculating the displacement.3. The civil engineering work data processing device according to claim 1 , wherein the processor or circuitry is further configured to calculate a position at the civil engineering work target claim 1 , into which the member is to be pushed claim 1 , on the basis of the estimated three-dimensional model.4. The civil engineering work data processing device according to claim 1 , wherein the processor or circuitry is further configured to calculate a direction ...

Evaluating Production Performance For A Wellbore While Accounting For Subterranean Reservoir Geomechanics And Wellbore Completion

Embodiments of evaluating production performance for a wellbore while accounting for subterranean reservoir geomechanics and wellbore completion are provided. One embodiment includes generating the wellbore model; defining geomechanical properties for the subterranean reservoir in the near wellbore region and the far field region, and completion variables for the wellbore completion; and simulating fluid flow in the near wellbore region, the far field region, and the wellbore completion to evaluate production performance for the wellbore over a period of time. A permeability of the subterranean reservoir and a contact area between the wellbore and the subterranean reservoir are updated during simulation over the period of time. The permeability and the contact area are updated as a function of a change in pressure and the geomechanical properties for the subterranean reservoir in the near wellbore region and the far field region, the completion variables for the wellbore completion, or any combination thereof. 1. A computer-implemented method of evaluating production performance for a wellbore while accounting for subterranean reservoir geomechanics and wellbore completion , the method comprising:generating a wellbore model defining a subterranean reservoir with a wellbore, wherein the subterranean reservoir comprises a near wellbore region and a far field region that is different than the near wellbore region, and wherein the wellbore comprises a wellbore completion;defining geomechanical properties for the subterranean reservoir in the near wellbore region and the far field region, and completion variables for the wellbore completion; andsimulating fluid flow in the near wellbore region, the far field region, and the wellbore completion to evaluate production performance for the wellbore over a period of time, wherein a permeability of the subterranean reservoir and a contact area between the wellbore and the subterranean reservoir are updated during simulation ...

HYDRAULIC FRACTURING, COMPLETION, AND DIVERTER OPTIMIZATION METHOD FOR KNOWN WELL ROCK PROPERTIES

A method for optimizing hydraulic fracturing includes characterizing a fracture induced by pumping fracturing fluid into a subsurface formation. The characterizing includes analyzing properties of reflected tube waves detected in a well. Change in expected characterization of the subsurface formation is modeled with respect to a modeled change in at least one parameter of the pumping fracturing fluid. The modeled change is compared to a measured change in the characterization with respect to an actual change in the at least one parameter. The modeled change and the measured change are used to train a machine learning algorithm to determine an optimized change in the at least one parameter. 1. A method for optimizing hydraulic fracturing , comprising:characterizing a fracture induced by pumping fracturing fluid into a subsurface formation, the characterizing comprising analyzing properties of reflected tube waves detected in a well;modeling change in expected characterization of the subsurface formation with respect to a modeled change in at least one parameter of the pumping fracturing fluid;comparing the modeled change to a measured change in the characterization with respect to an actual changes in the at least one parameter; andusing the modeled change and the measured change to train a machine learning algorithm to determine an optimized change in the at least one parameter.2. The method of wherein the at least one parameter comprises at least one of pad volume claim 1 , fracture fluid viscosity claim 1 , fracture fluid density claim 1 , propping agent type claim 1 , propping agent volume claim 1 , fracturing fluid Injection rate and fracture fluid volume.3. The method of wherein the characterizing a fracture comprises analyzing a far field fracture system property and a near field fracture system property.4. The method of wherein the analyzing the far field fracture property comprises analyzing pressure decay after completing pumping the fracturing fluid.5. The ...

MULTI-AGENT DRILLING DECISION SYSTEM AND METHOD

A method for drilling a well includes generating a plurality of proposed drilling actions using a plurality of working agents based on a working environment, simulating drilling responses to the proposed drilling actions using a plurality of validation agents in a validation environment that initially represents the working environment, determining rewards for the proposed drilling actions based on the simulating, using the validation agents, selecting one of the proposed drilling actions, and causing a drilling rig to execute the selected one of the proposed actions. 1. A method for drilling a well , comprising:generating a plurality of proposed drilling actions using a plurality of working agents based on a working environment;simulating drilling responses to the proposed drilling actions using a plurality of validation agents in a validation environment that initially represents the working environment;determining rewards for the proposed drilling actions based on the simulating, using the validation agents;selecting one of the proposed drilling actions; andcausing a drilling rig to execute the selected one of the proposed actions.2. The method of claim 1 , wherein selecting the one of the proposed actions is based on the rewards for the proposed actions.3. The method of claim 1 , wherein generating the plurality of proposed drilling actions comprises receiving an override action from a human user claim 1 , and wherein selecting the one of the proposed actions comprises selecting the override action in response to receiving the override action.4. The method of claim 1 , wherein generating the plurality of proposed drilling actions comprises receiving a manual proposed drilling action from a human user claim 1 , wherein simulating the drilling responses comprises simulating a drilling response to the manual proposed drilling action claim 1 , wherein determining the rewards comprises determining a reward for the manual proposed drilling action claim 1 , and wherein ...

SAFETY INTEGRITY LEVEL (SIL) 3 HIGH-INTEGRITY PROTECTION SYSTEM (HIPS) FULLY-FUNCTIONAL TEST CONFIGURATION FOR HYDROCARBON (GAS) PRODUCTION SYSTEMS

A selection of a hydrocarbon well of a hydrocarbon production system is received at a safety logic solver (SLS) for proof testing. Test mode pressure sensors attached to a common header of the hydrocarbon production system are activated to monitor a live process condition status of the common header from all wells of the hydrocarbon production system. A simulated overpressure condition is induced in the operation pressure sensors. An indication of overpressure is received at the SLS from at least two operation pressure sensors. Final elements associated with the hydrocarbon well are signaled to close while leaving other wells in the hydrocarbon production system in operation. The operation pressure sensors are restored to a normal pressure condition, and the final elements associated with the selected hydrocarbon well are signaled to re-open the hydrocarbon well. 1. A computer-implemented method , comprising:receiving a selection of a hydrocarbon well of a hydrocarbon production system at a safety logic solver (SLS) for proof testing;activating test mode pressure sensors attached to a common header of the hydrocarbon production system to monitor a live process condition status of the common header from all wells of the hydrocarbon production system;inducing a simulated overpressure condition in operation pressure sensors;receiving an indication of overpressure at the SLS from at least two operation pressure sensors;signaling final elements associated with the hydrocarbon well to close while leaving other wells in the hydrocarbon production system in operation;restoring the operation pressure sensors to a normal pressure condition; andsignaling the final elements associated with the selected hydrocarbon well to re-open the hydrocarbon well.2. The computer-implemented method of claim 1 , wherein the monitored live process condition is whether the hydrocarbon production system is below a high-pressure set point value.3. The computer-implemented method of claim 1 , ...

Computer implemented method for manipulating a mesh for the discretization of a reservoir domain

A computer-implemented method for manipulating a mesh for the discretization of a reservoir domain, the reservoir domain modeled by a geophysical model, a fluid model, or both models. The method includes the use of cells partitioning the reservoir domain wherein each cell includes a numerical mesh. The mesh of the reservoir domain is the union of the meshes located in the plurality of cells. The partitioning of the domain into a plurality of cells allows easy modification of specific regions of the domain wherein re-meshing requirements are limited to those cells housing modified elements and maybe some surrounding cells.

WELL OPERATIONS INVOLVING SYNTHETIC FRACTURE INJECTION TEST

A system includes a processing device and a non-transitory computer-readable medium having instructions stored thereon that are executable by the processing device to cause the system to perform operations. The operations include generating and running a reservoir simulation model. The reservoir and simulation model includes representative natural fracture or secondary porosity attributes for an area of interest for one or more wells. The operations also include generating a synthetic G-function response using results of the reservoir simulation model. Additionally, the operations include calibrating the synthetic G-function response from the reservoir simulation model to a field G-function response generated using results of a field diagnostic fracture injection test by changing natural fracture characteristics of the reservoir simulation model. Further, the operations include formulating a drilling plan, a completion plan, or both for a wellbore in the area of interest using the synthetic G-function response. 1. A system comprising:a processing device; and generating and running a reservoir simulation model, including representative natural fracture or secondary porosity attributes for an area of interest for one or more wells;', 'generating a synthetic G-function response using results of the reservoir simulation model;', 'calibrating the synthetic G-function response from the reservoir simulation model to a field G-function response generated using results of a field diagnostic fracture injection test by changing natural fracture characteristics of the reservoir simulation model; and', 'formulating a drilling plan, a completion plan, or both for a wellbore in the area of interest using the synthetic G-function response., 'a non-transitory computer-readable medium having instructions stored thereon that are executable by the processing device to cause the system to perform operations, the operations comprising2. The system of claim 1 , wherein the instructions ...

PROBABILISTIC MODEL CALIBRATION AND ESTIMATION FOR DRILLING STEERING CONTROL

A method for calibrating a steering model may comprise estimating an initial condition for one or more variables in the steering model and calibrating the steering model with a Markov Chain Monte Carlo Simulation (MCMC). A drilling system may comprise a bottom hole assembly, a drill string connected to the bottom hole assembly, and an information handling system connected to the bottom hole assembly. The information handling system may be configured to process one or more measurements from the bottom hole assembly, calibrate a steering model based at least in part on the one or more measurements, adjust a control logic based at least in part on the steering model, and adjust the bottom hole assembly based at least in part on the control logic. 1. A method for calibrating a steering model comprising:estimating an initial condition for one or more variables in the steering model; andcalibrating the steering model with a Markov Chain Monte Carlo Simulation (MCMC).2. The method of further comprising estimating a measurement uncertainty based at least in part on the one or more variables.3. The method of further comprising updating a prior probability distribution for the one or more variables based at least in part on one or more posterior probabilities.4. The method of claim 1 , further comprising calculating a probability distribution for the one or more variables in the steering model.5. The method of claim 4 , further comprising fitting the one or more variables to the steering model by minimizing an objective function.6. The method of claim 5 , further comprising performing a sum of squares of the objective function.7. The method of claim 1 , further comprising identifying a window at an initial depth for the estimating the initial condition.8. The method of claim 7 , further comprising selecting a random sample of measurements.9. The method of claim 8 , further comprising performing a least-squares linear fit on the random sample of measurements.10. The method of ...

DRILLING SYSTEM

A method can include acquiring drilling performance data for a downhole tool; modeling drilling performance of the downhole tool to generate results; training a machine learning model using the drilling performance data and the results to generate a trained machine learning model; and predicting behavior of the downhole tool using the trained machine learning model. 1. A method comprising:acquiring drilling performance data for a downhole tool;modeling drilling performance of the downhole tool to generate results;training a machine learning model using the drilling performance data and the results to generate a trained machine learning model; andpredicting behavior of the downhole tool using the trained machine learning model.2. The method of claim 1 , comprising claim 1 , based at least on the predicting behavior of the downhole tool claim 1 , selecting the downhole tool for drilling a borehole.3. The method of claim 1 , comprising generating a digital well plan to drill a borehole using the downhole tool.4. The method of claim 1 , comprising programming a controller using the trained machine learning model and controlling a drilling operation using the controller.5. The method of claim 1 , wherein the modeling drilling performance of the downhole tool comprises utilizing a physics-based model.6. The method of claim 1 , wherein the machine learning model comprises a Gaussian process model.7. The method of claim 1 , wherein the trained machine learning model comprises an ensemble model.8. The method of claim 1 , wherein the training the machine learning model using the drilling performance data and the results to generate a trained machine learning model comprising computing residuals.9. The method of claim 8 , wherein the residuals comprise errors between the drilling performance data and the results and/or wherein the residuals comprise values with respect to a trajectory claim 8 , wherein the trajectory comprises a dogleg.10. The method of claim 1 , comprising ...

RISK ASSESSMENT-BASED DESIGN METHOD FOR DEEP COMPLEX FORMATION WELLBORE STRUCTURE

A risk assessment-based design method for a deep complex formation wellbore structure includes: (1) preliminarily determining casing layers and setting depths; (2) calculating to obtain the risk coefficients of each layer of casing; (3) analyzing and coordinating, according to the principle that a shallow casing shares more risks and a deep casing shares less risks, the risks of each layer of casing: determining whether the risk coefficients of each layer of casing are greater than a safety threshold value K; checking the setting depth: if the safety coefficient of an ith-layer casing satisfies R>K, selecting a casing layer with the minimum safety coefficient from upper casing layers, and deepening the setting depth h of the casing layer; and (4) repeating the steps (2) to (3) until the casing risk coefficients of each layer of casing are less than the safety threshold value K. 2. The risk assessment-based drilling method according to claim 1 , wherein the method in the step (i) further comprises:(a) measuring a geological setting position;(b) creating, by the processor, a safety pressure window based on prediction results of formation pore pressure, formation fracture pressure and formation collapse pressure before drilling and a pressure balance relationship of an open hole section; and(c) generating, by the processor, the casing layers and the setting depth based on the geological setting position, the safety pressure window and a regional wellbore structure design coefficient. This application is the continuation-in-part application of U.S. application Ser. No. 17/033,849 Filed on 27 Sep. 2020 which claims priority to Chinese Application No. CN2019111037553 filed on 13 Nov. 2019, the entire contents of each of which are hereby incorporated by reference.The present invention relates to a risk assessment-based design method for a deep complex formation wellbore structure, and belongs to the technical field of oil and gas drilling.Wellbore structure design is one ...

3D IN-SITU CHARACTERIZATION METHOD FOR HETEROGENEITY IN GENERATING AND RESERVING PERFORMANCES OF SHALE

The present invention discloses a three-dimensional in-situ characterization method for heterogeneity in generating and reserving performances of shale. The method includes the following steps: establishing a logging in-situ interpretation model of generating and reserving parameters based on lithofacies-lithofacies-well coupling, and completing single-well interpretation; establishing a 3D seismic in-situ interpretation model of generating and reserving parameters by using well-seismic coupling; establishing a spatial in-situ framework of a layer group based on lithofacies-well-seismic coupling, and establishing a spatial distribution trend framework of small layers of a shale formation by using 3D visualized comparison of a vertical well; and implementing 3D in-situ accurate characterization of shale generating and reserving performance parameters by using lithofacies-well-seismic coupling based on the establishment of the seismic-lithofacies dual-control parameter field. The present invention integrates an in-situ technology into shale logging, seismic generating and reserving parameter interpretation, and the establishment of a 3D mesh model of small layers of shale, which realizes the accurate description of the heterogeneity in TOC content and porosity value of shale oil and gas in a 3D space, and provides a reliable technical support for shale oil and gas exploration and development. 1. A three-dimensional in-situ characterization method for heterogeneity in generating and reserving performances of shale , comprising the following steps:{'b': '1', 'S: establishing a logging in-situ interpretation model of generating and reserving parameters based on lithofacies-lithofacies-well coupling, and completing point-by-point interpretation of generating and reserving parameters of a single well;'}{'b': '2', 'S: establishing an optimal well-seismic coupling interpretation model that characterizes the TOC content and porosity of a shale formation based on well-seismic ...

PREDICTING DOWNHOLE MECHANICAL CLEANING EFFICIENCY IN WELLBORE WALLS DURING WELLBORE FLUIDS DISPLACEMENTS

Predicting the efficiency of downhole mechanical removal of one or more accreted materials from one or more wellbore walls may prevent the unnecessary consumption of resources in a wellbore fluids displacement operation. A method and system for removing accreted materials in a wellbore is provided, wherein the efficiency of mechanical removal of accreted materials may be characterized based, at least in part, on a comparison between one or more actual shear stresses exerted by a wellbore servicing fluid at one or more depths of the wellbore and one or more required shear stresses to remove the accreted materials from the depth. The one or more required shear stresses may be determined using one or more of one or more known properties of the one or more accreted materials, one or more rheology models, one or more hydraulic parameters, one or more wellbore hydraulic models, and one or more downhole conditions. To account for one or more effects of eccentricity in the wellbore, the one or more actual shear stresses exerted by wellbore servicing fluid may be determined by partitioning one or more three dimensional flow profiles into divided annular segments for individual analysis. To improve operational decision making, operators or automated processes may modify the wellbore fluids displacement operation based, at least in part, on the comparison. The comparison between the one or more actual shear stresses and the one or more required shear stresses may be used to generate a parameter that characterizes the cleaning efficiency of the wellbore fluids displacement operation. 1. A method for removal of accreted materials in a wellbore comprising:flowing a wellbore servicing fluid through a fluid flow path of a wellbore;determining a required shear stress to remove the accreted materials from a depth in the wellbore;determining one or more three dimensional flow profiles for the wellbore servicing fluid;dividing the one or more three dimensional flow profiles into a ...

Systems and methods for analyzing casing bonding in a well using differential sensing

Implementations described and claimed herein provide systems and methods for isolation detection. In one implementation, an acoustic signal is obtained. The acoustic signal is captured at a set of acoustic receivers deployed in a structure in a subterranean surface. A differential acoustic signal is produced from the acoustic signal captured at the set of acoustic receivers. A symmetry within a portion of the structure is determined based on a value of the differential acoustic signal. At least one isolation region is detected within the structure based on the symmetry.

Methods For Modeling Multiple Simultaneously Propagating Hydraulic Fractures

Methods for modeling hydraulic fractures using a geomechanical model of a formation and a completion design that includes a plurality of hydraulic fractures. A quantity of equivalent hydraulic fractures is selected to represent the plurality of hydraulic fractures. An equivalence ratio is determined using the quantity of equivalent hydraulic fractures and a fracture regime based on the geomechanical model and the completion design. The equivalence ratio is then used to update the geomechanical model and the completion design used as modeling inputs. The modeling results can then be modified using the equivalence ratio to compute a total surface area and fracture width of the plurality of hydraulic fractures. 1. A method for modeling hydraulic fractures comprising:selecting a geomechanical model of a formation;selecting a completion design for a well within the formation, wherein the completion design includes a plurality of hydraulic fractures;selecting one or more equivalent hydraulic fractures to represent the plurality of hydraulic fractures;determining an equivalence ratio based on the one or more equivalent hydraulic fractures;updating the geomechanical model and the completion design using the equivalence ratio;modeling a total surface area and fracture width of the one or more equivalent hydraulic fractures using the updated geomechanical model and the updated completion design; andcomputing a total surface area and fracture width of the plurality of hydraulic fractures using the equivalence ratio and the modeled total surface area and fracture width of the one or more equivalent hydraulic fractures.2. The method of claim 1 , wherein the total surface area of the plurality of hydraulic fractures is computed by multiplying the total surface area of the one or more equivalent hydraulic fractures by the equivalence ratio.3. The method of claim 1 , wherein the fracture width of the plurality of hydraulic fractures is computed by dividing the fracture width of the ...

Determination Of Hydrocarbon Production Rates For An Unconventional Hydrocarbon Reservoir

Methods for predicting hydrocarbon production rates for a hydrocarbon reservoir include receiving data from a hydrocarbon reservoir. The data includes reservoir characterization data, well log data, and hydraulic fracturing data. A physics-constrained machine learning model predicts a hydrocarbon production rate for the hydrocarbon reservoir as a function of time. The physics-constrained machine learning model includes an artificial neural network and a hydrocarbon fluid flow model. Predicting the hydrocarbon production rate includes generating, by the artificial neural network, multiple parameters of the hydrocarbon fluid flow model based on the data from the hydrocarbon reservoir. The hydrocarbon fluid flow model provides the predicted hydrocarbon production rate as a function of time based on the parameters. A display device of the computer system presents the predicted hydrocarbon production rate for the hydrocarbon reservoir as a function of time. 1. A method comprising:receiving, by a computer system, data from a hydrocarbon reservoir, the data comprising reservoir characterization data, well log data, and hydraulic fracturing data of the hydrocarbon reservoir, the computer system comprising a physics-constrained machine learning model; generating, by the artificial neural network, a plurality of parameters of the hydrocarbon fluid flow model based on the data from the hydrocarbon reservoir, the hydrocarbon fluid flow model communicably coupled to the artificial neural network; and', 'providing, by the hydrocarbon fluid flow model, the predicted hydrocarbon production rate as a function of time based on the plurality of parameters; and, 'generating, by the physics-constrained machine learning model, a predicted hydrocarbon production rate for the hydrocarbon reservoir as a function of time, the physics-constrained machine learning model comprising an artificial neural network and a hydrocarbon fluid flow model of the hydrocarbon reservoir, the generating of ...

SYSTEMS AND METHODS FOR DETERMINING GRID CELL COUNT FOR RESERVOIR SIMULATION

Systems, methods and computer readable storage media for optimizing a determination of a number of grid cell counts to be used in creating the geocellular grid of an earth, geomechanical or petro-elastic model for reservoir simulation. These may involve determining at least one processing time for a simulation; determining a grid cell count to be used in creating a geocellular grid for the simulation based on the at least one processing time and a number of processors to be used for creating the model; creating the geocellular grid using the grid cell count, and generating a model for the simulation using the geocellular grid. 1. A predictive modeling method comprising:determining at least one processing time for a simulation;determining a grid cell count to be used in creating a geocellular grid for the simulation based on the at least one processing time and a number of processors to be used for creating the model;creating the geocellular grid using the grid cell count; andgenerating a model for the simulation using the geocellular grid.2. The predictive modeling method of claim 1 , further comprising:receiving a first input, a second input and at least one third input, the first input specifying a simulation time for using a simulation platform to create the model, the second input specifying a duration of time over which an underlying object is to be simulated, the at least one third input identifying a time step for the simulation; anddetermining the at least one processing time based on the first input, the second input and the at least one third input3. The predictive modeling method of claim 1 , wherein the at least one third input includes a minimum time step and a maximum time step.4. The predictive modeling method of claim 3 , wherein the at least one processing time includes a minimum processing time corresponding to the minimum time step and a maximum processing time corresponding to the maximum time step.5. The predictive modeling method of claim 1 , ...

IDENTIFICATION OF WELLBORE DEFECTS USING MACHINE LEARNING SYSTEMS

A method for identifying defects in a multi-barrier wellbore includes receiving log data, the log data corresponding to one or more wellbore operations, the log data including data from at least one measurement modality corresponding to a present measurement modality. The method also includes training, using the log data, a machine learning model. The method further includes acquiring wellbore data, via the present measurement modality, during a logging operation. The method also includes processing at least a portion of the wellbore data using the trained machine learning model. The method includes identifying one or more features of interest in the wellbore data, via the trained machine learning model. 1. A method for detecting a wellbore defect , comprising:receiving, at a trained machine learning system, input data, the input data corresponding to log data for a wellbore operation in a multi-barrier wellbore;processing, using a first classifier of the machine learning system, the input data;identifying, using the first classifier of the machine learning system, a feature of interest associated with the input data;receiving, at a second classifier of the machine learning system, first output data from the first classifier and the input data, the first output data corresponding to a defect associated with the wellbore;receiving, at a third classifier of the machine learning system, second output data from the second classifier and the input data, the second output data corresponding to a first property of the defect; andproviding a report corresponding to the defect, the first property of the defect, and a second property of the defect corresponding to third output data.2. The method of claim 1 , further comprising:pre-processing the input data before the data is received at the trained machine learning system, the pre-processing including at least one of data filtering or data normalization.3. The method of claim 1 , further comprising:training the machine ...

INTEGRATED THERMAL AND STRESS ANALYSIS FOR A MULTIPLE TUBING COMPLETION WELL

A well operation simulator predicts temperature and pressure profiles of a multi-tubing completion well for well design. The simulator is comprised of modules, which when executed, determine a first set of design limits based on stress conditions arising from the temperature and pressure profiles from a multi-tubing drilling module and a multi -tubing production module for drilling and production operations. A multi-tubing multi-string module predicts the annular fluid expansion (AFE) and annular pressure buildup (APB) of the multi-tubing well from the previously calculated temperature profile, pressure profile, and stress conditions and determines a second set of design limits with the AFE/APB effects in addition to the temperature profile and pressure profile predicted from multi-tubing drilling module and multi-tubing production module. The first and second sets of design limits are depicted using one or 1. A method comprising:simulating a production operation for a described well with multiple tubings to determine a production temperature profile and a production pressure profile for the described well based on a flow path of each tubing, shared annulus fluid, and tubing surface-based heating coefficient of each tubing;for each of the multiple tubings, determining a production pressure profile and a production temperature profile based, at least in part, on the production and temperature profiles for the described well;performing a stress simulation based on the production temperature and pressure profiles of the multiple tubings to predict stress state of the described well;determining a first set of design limitations of the described well based on: the predicted stress state of the multiple tubings, one or more casings of the described well, or combinations thereof;simulating a drilling operation for the described well to determine a drilling temperature profile and a drilling pressure profile for the described well;determining a trapped annular pressure ...

Estimate active-adjacent borehole interference severity

This disclosure presents processes to determine whether a leak-off event is occurring during the treatment stage of an active borehole. The leak-off event data, such as the severity or magnitude of the potential leak-off, can be communicated to other systems to adjust the treatment stage, the fluid composition, the fluid pressure, or the fluid flow rate. Diverter material can be added to the fluid. The monitoring of the leak-off event can occur over a time interval, such as the time of the treatment stage and periodic adjustments to the treatment stage can be implemented. The leak-off event can be identified when a fluid pressure slope indicates an overall increase in pressure in an adjacent borehole or if the amount of fluid entering an adjacent borehole exceeds a leak-off threshold.

Method and system for predicting production of fractured horizontal well in shale gas reservoir

The present disclosure relates to a method and system for predicting the production of a fractured horizontal well in a shale gas reservoir, and relates to the technical field of fractured horizontal wells. Considering the different diffusion modes of the matrix in different zones, the present disclosure uses Fick's First Law to describe the pseudo-steady-state diffusion of the matrix in the fracture network zone, Fick's Second Law to describe the unsteady-state diffusion of the matrix in the pure matrix zone, and Darcy's Law to describe the seepage in the fracture network. The present disclosure predicts the production of the fractured horizontal well in the shale gas reservoir under the conditions of matrix-microfracture coupling and hydraulically created fracture-microfracture coupling. The present disclosure improves the prediction accuracy of shale gas well production, and more accurately describes the actual flow law of the shale gas reservoir.

ENHANCED-RESOLUTION SONIC DATA PROCESSING FOR FORMATION BODY WAVE SLOWNESS WITH FULL OFFSET WAVEFORM DATA

Apparatus, methods, and systems for determining body wave slowness values for a target formation zone. A method includes selecting a target axial resolution based on the size of a receiver array, obtaining a plurality of waveform data sets corresponding to a target formation zone and each acquired at a different shot position, reconstructing the plurality of waveform data sets to generate a plurality of subarray data sets corresponding to the target formation zone, determining a slowness value for each subarray data set and determining a slowness versus offset value for each subarray data set. The method may also include generating a borehole model having at least one alteration formation zone and a virgin formation zone and generating a slowness versus offset model based at least in part on the borehole model. The method may also include determining a radial depth of the alteration formation zone. 1. A method of determining body wave slowness values for a target formation zone , the method comprising:selecting a target axial resolution based on the size of a receiver array;obtaining a plurality of waveform data sets corresponding to a target formation zone, wherein each waveform data set is acquired at a different shot position;reconstructing the plurality of waveform data sets to generate a plurality of subarray data sets corresponding to the target formation zone;determining a slowness value for each subarray data set;determining a slowness versus offset value for each subarray data set;generating a borehole model having at least one alteration formation zone and a virgin formation zone;generating a slowness versus offset model based at least in part on the borehole model;optimizing the parameters in the borehole model by minimizing a misfit between the slowness value for each subarray data set and the borehole model and the slowness versus offset model to generate an optimized borehole model and an optimized slowness versus offset model;extracting a virgin ...