Abstract: A method is performed for defining optimal landing location(s) of horizontal wells for hydraulic fracturing stimulation, for improved well performance of unconventional reservoirs. The method includes evaluating one or more planes of weakness, pinch-out points, or thin rock layering in the reservoir that may impede hydraulic fracture growth or may close fractured sections during production. The method can include conducting detailed analysis on core and open hole logs, and defining the presence, density, orientation, spacing, and mechanical properties of various thin interfaces and barriers in the rock mass. The method can include classifying the barriers or thin interfaces based on their effect on hydraulic fracture growth or fracture connectivity, and on uncertainty of their effect.

Abstract: A method comprising calibrating a geomodel by comparing data indicative of fracture-to-fracture interactions from a completed multi-stage hydraulic fracturing process to data from a simulated multi-stage hydraulic fracturing process. In particular, the method includes comparing a simulated instantaneous shut-in pressure and a simulated wellhead pressure to a measured instantaneous shut-in pressure and a measured wellhead pressure. Based on this comparison, one or more properties of the geomodel are adjusted and the multi-stage hydraulic fracturing process is re-simulated until the simulated values are substantially equivalent to the measured values.

Abstract: Methods for simulating the movement of fluid through a formation volume comprises defining a lab-scale model representing rock fabric and associated permeability along a single well location within a formation volume and converting the lab-scale model to a field-scale model representing rock fabric and associated permeability at the single well location. The field-scale model representing rock fabric and associated permeability is correlated with field-scale log data and interpolated between multiple well locations so as to create a field-scale model representing rock fabric and associated permeability across the formation volume so that the movement of fluid through the formation volume can be simulated.

Abstract: 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.

Abstract: Methods for constructing a regional-scale geomodel by obtaining high-resolution stratigraphic data at a plurality of locations within an area of interest. A regional-scale resolution can be selected based on one or more identified structural features at the plurality of locations and the high-resolution stratigraphic data homogenized to the regional-scale resolution so as to generate regional-scale stratigraphic data. This homogenization is performed using a technique that preserves energy consumption during fracture propagation. The regional-scale stratigraphic data is then interpolated between the plurality of locations so as to create a regional-scale geomodel in the area of interest that can be used to perform numerical simulations of hydraulic fracturing using the regional-scale geomodel.

Abstract: A method for characterizing properties of a sample that employs a test apparatus including an isolated sample cell and pressure sensor where the isolated sample cell is loaded with the sample and gaseous test fluid to perform a number of different tests to derive properties of the sample. The tests can be performed over different parameters, such as different applied pressures of the test fluid to derive parameters related to apparent gas permeability of the sample as a function of applied pressure, different gaseous test fluids to characterize dependence of permeability of the sample on mean free molecular path or pressure, with both adsorptive and non-adsorptive test gases to characterize at least one property related to adsorptive interaction between the adsorptive test gas and the sample, and with samples of varying saturation levels to derive a measure of at least one property of the subsamples at corresponding saturation levels.

Abstract: Methods for simulating the movement of fluid through a formation volume comprises defining a lab-scale model representing rock fabric and associated permeability along a single well location within a formation volume and converting the lab-scale model to a field-scale model representing rock fabric and associated permeability at a single well location. The field-scale model representing rock fabric and associated permeability is correlated with field-scale log data and interpolated between multiple well locations so as to create a field-scale model representing rock fabric and associated permeability across the formation volume so that the movement of fluid through the formation volume can be simulated.

Abstract: A method is performed for defining optimal landing location(s) of horizontal wells for hydraulic fracturing stimulation, for improved well performance of unconventional reservoirs. The method includes evaluating one or more planes of weakness, pinch-out points, or thin rock layering in the reservoir that may impede hydraulic fracture growth or may close fractured sections during production. The method can include conducting detailed analysis on core and open hole logs, and defining the presence, density, orientation, spacing, and mechanical properties of various thin interfaces and barriers in the rock mass. The method can include classifying the barriers or thin interfaces based on their effect on hydraulic fracture growth or fracture connectivity, and on uncertainty of their effect.

Abstract: A method is performed for defining optimal landing location(s) of horizontal wells for hydraulic fracturing stimulation, for improved well performance of unconventional reservoirs. The method includes evaluating one or more planes of weakness, pinch-out points, or thin rock layering in the reservoir that may impede hydraulic fracture growth or may close fractured sections during production. The method can include conducting detailed analysis on core and open hole logs, and defining the presence, density, orientation, spacing, and mechanical properties of various thin interfaces and barriers in the rock mass. The method can include classifying the barriers or thin interfaces based on their effect on hydraulic fracture growth or fracture connectivity, and on uncertainty of their effect.

Abstract: A method for characterizing properties of a sample that employs a test apparatus including an isolated sample cell and pressure sensor where the isolated sample cell is loaded with the sample and gaseous test fluid to perform a number of different tests to derive properties of the sample. The tests can be performed over different parameters, such as different applied pressures of the test fluid to derive parameters related to apparent gas permeability of the sample as a function of applied pressure, different gaseous test fluids to characterize dependence of permeability of the sample on mean free molecular path or pressure, with both adsorptive and non-adsorptive test gases to characterize at least one property related to adsorptive interaction between the adsorptive test gas and the sample, and with samples of varying saturation levels to derive a measure of at least one property of the subsamples at corresponding saturation levels.

Abstract: Disclosed is a method and system for integrating measurements from known laboratory techniques of fluid extraction (Dean Stark, Retort, Rock-Eval), which conducted independently by multiple disciplines and which have been so far treated as independent evaluations. In using these results, particularly Dean Stark and Retort, the oil industry has shown specific preferences between these two methods, with some groups advocating the validity of one method over the other, and others showing the opposite. Forums and discussions have been organized by the technical community to debate the benefits and drawbacks of each of these and to define which is the more suitable for reservoir characterization. Commercial laboratories have specialized in one method or the other based on their perceived validity. Both methods are correct, but each measure an incomplete assessment of the properties needed, and that together they provide considerable more information than when considered independently.

Abstract: A workflow is provided that characterizes the hydraulic fracturability of a rock based on properties obtained from CT scanning and from non-CT based data. The characterization is based on obtaining a plurality of properties of a core sample as a function of axial location in the core sample. The workflow includes obtaining CT data from at least one CT scan of the core, obtaining heterogeneity data of the core, generating a heterogeneous rock analysis (HRA) model based at least on the obtained CT data and heterogeneity data; quantifying statistically significant distinct rock classes in the core, and assigning hydraulic fracturability index (HFI) values to each distinct rock class, as well as any HFI variation within each rock class. An HFI value is assigned to each rock class, and within a rock class, in the core and those values can be propagated to other locations in the same or surrounding wells.

Abstract: A method for characterizing properties of a sample that employs a test apparatus including an isolated sample cell and pressure sensor where the isolated sample cell is loaded with the sample and gaseous test fluid to perform a number of different tests to derive properties of the sample. The tests can be performed over different parameters, such as different applied pressures of the test fluid to derive parameters related to apparent gas permeability of the sample as a function of applied pressure, different gaseous test fluids to characterize dependence of permeability of the sample on mean free molecular path or pressure, with both adsorptive and non-adsorptive test gases to characterize at least one property related to adsorptive interaction between the adsorptive test gas and the sample, and with samples of varying saturation levels to derive a measure of at least one property of the subsamples at corresponding saturation levels.

Abstract: A method for characterizing properties of a porous sample that employs a test apparatus including a sample cell and associated pressure sensor having a configuration that measures pressure of the isolated sample cell. The porous sample is divided into a number of pieces, which are loaded into the sample cell. The test apparatus is configured to perform a sequence of test operations whereby the loaded isolated sample cell is filled with test fluid under pressure and the pressure sensor is used to generate and store pressure data over time. A data processing system processes the pressure data in conjunction with a computational model that includes a set of pressure curves with a number of curve-related variables and associated values in order to identify a matching pressure curve, and processes the variable values for the matching pressure curve in order to derive bulk properties of the porous sample.

Abstract: A method for characterizing properties of a manufactured rock sample that employs first and second test apparatus. The first test apparatus includes a sample holder and associated pressure sensors, wherein the sample holder allows for a pulse of test fluid to flow through the sample, and the pressure sensors measure pressure upstream and downstream of the sample as the pulse of test fluid flows through the sample. The second test apparatus includes a sample cell and associated pressure sensor, wherein the sample cell has a configuration where the sample cell is isolated and filled with test fluid under pressure and the pressure sensor measures pressure of the isolated sample cell. The first and second test apparatus are used to measure bulk properties of the sample. The sample is partitioned into pieces, and the second test apparatus is used to measure properties for different size-groups of such sample pieces.

Abstract: A test apparatus (and method of operation) for characterizing properties of a sample under test (such as porous material, for example, samples of reservoir rock) that operates in conjunction with a source of test fluid. The test apparatus includes an intake valve fluidly coupled to the source of test fluid, a reference cell fluidly coupled to the source of test fluid via the intake valve, a sample cell that holds the sample under test, an isolation valve fluidly coupled between the reference cell and the sample cell, an exhaust port, an exhaust valve fluidly coupled between the sample cell and the exhaust port, a first pressure sensor associated with the reference cell for measuring pressure within the reference cell, and a second pressure sensor associated with the sample cell for measuring pressure within the sample cell. The method of operation includes calibration procedures to compensate for systematic measurement errors.

Abstract: Disclosed is a method and system for integrating measurements from known laboratory techniques of fluid extraction (Dean Stark, Retort, Rock-Eval), which conducted independently by multiple disciplines and which have been so far treated as independent evaluations. In using these results, particularly Dean Stark and Retort, the oil industry has shown specific preferences between these two methods, with some groups advocating the validity of one method over the other, and others showing the opposite. Forums and discussions have been organized by the technical community to debate the benefits and drawbacks of each of these and to define which is the more suitable for reservoir characterization. Commercial laboratories have specialized in one method or the other based on their perceived validity. Both methods are correct, but each measure an incomplete assessment of the properties needed, and that together they provide considerable more information than when considered independently.

Abstract: A method is performed for defining optimal landing location(s) of horizontal wells for hydraulic fracturing stimulation, for improved well performance of unconventional reservoirs. The method includes evaluating one or more planes of weakness, pinch-out points, or thin rock layering in the reservoir that may impede hydraulic fracture growth or may close fractured sections during production. The method can include conducting detailed analysis on core and open hole logs, and defining the presence, density, orientation, spacing, and mechanical properties of various thin interfaces and barriers in the rock mass. The method can include classifying the barriers or thin interfaces based on their effect on hydraulic fracture growth or fracture connectivity, and on uncertainty of their effect.

Abstract: A method for characterizing properties of a manufactured rock sample that employs first and second test apparatus. The first test apparatus includes a sample holder and associated pressure sensors, wherein the sample holder allows for a pulse of test fluid to flow through the sample, and the pressure sensors measure pressure upstream and downstream of the sample as the pulse of test fluid flows through the sample. The second test apparatus includes a sample cell and associated pressure sensor, wherein the sample cell has a configuration where the sample cell is isolated and filled with test fluid under pressure and the pressure sensor measures pressure of the isolated sample cell. The first and second test apparatus are used to measure bulk properties of the sample. The sample is partitioned into pieces, and the second test apparatus is used to measure properties for different size-groups of such sample pieces.

Abstract: A test apparatus (and method of operation) for characterizing properties of a sample under test (such as porous material, for example, samples of reservoir rock) that operates in conjunction with a source of test fluid. The test apparatus includes an intake valve fluidly coupled to the source of test fluid, a reference cell fluidly coupled to the source of test fluid via the intake valve, a sample cell that holds the sample under test, an isolation valve fluidly coupled between the reference cell and the sample cell, an exhaust port, an exhaust valve fluidly coupled between the sample cell and the exhaust port, a first pressure sensor associated with the reference cell for measuring pressure within the reference cell, and a second pressure sensor associated with the sample cell for measuring pressure within the sample cell. The method of operation includes calibration procedures to compensate for systematic measurement errors.