Abstract: Systems and methods described herein provide for the estimation of the maximum reservoir pressure at which fluid can be injected into a reservoir before causing conductivity increase due to fracture/fault reactivation. An exemplary method includes computing the maximum reservoir pressure for the location of interest prior to fracture/fault reactivation at a given depleted reservoir pressure based on a computed probability of non-exceedance for a field or laboratory estimate of the maximum reservoir pressure prior to fracture/fault reactivation and a computed pressure distribution including a range of potential maximum reservoir pressures for the location of interest prior to fracture/fault reactivation at the given depleted reservoir pressure. The method also includes outputting the computed maximum reservoir pressure as the estimated maximum reservoir pressure for performing a fluid injection operation for the location of interest.

Abstract: A method of operating a telemetry system includes automatically populating a base field of a schema in an event definition using a logging library of the telemetry system for an event of an instrumented application, and automatically populating a conditional field of the schema in the event definition using the logging library in response to a selected condition for the event.

Abstract: A method of operating a telemetry system includes automatically populating a first set of fields in a schema of an event definition using a logging library of the telemetry system, and receiving the set of fields via a request message in an application protocol.

Abstract: A method of operating a telemetry system includes automatically populating a first set of fields in a schema of an event definition using a logging library of the telemetry system, and populating a second set of fields in the schema selected by an event author.

Abstract: A method of operating a telemetry system includes automatically populating a base field of a schema in an event definition using a logging library of the telemetry system for an event of an instrumented application, and automatically populating a conditional field of the schema in the event definition using the logging library in response to a selected condition for the event.

Abstract: A method of operating a telemetry system includes automatically populating a base field of a schema in an event definition using a logging library of the telemetry system for an event of an instrumented application, and automatically populating a conditional field of the schema in the event definition using the logging library in response to a selected condition for the event.

Abstract: The present disclosure describes methods and systems to enhance subsurface models of fractured reservoirs. In particular, the methods and systems described herein incorporate the effects of “dynamic” compressible fractures and, thus, can improve predictions of fractured reservoir performance over time. The methods and systems may utilize predictive algorithms for mechanical and hydraulic stiffness properties of the fracture network that are based at least in part on a database of measurements derived from single fractures.

Abstract: Method and system is described for modeling one or more strength properties of a subsurface volume. The method provides an enhanced process for upscaling to simplify data in a manner that accounts for problems with conventional techniques. The method involves simplifying the petrophysical data and/or layers to provide an upscaling approach that accounts for the influences on the strength properties. The properties may then be utilized to enhance a subsurface model and used to enhance hydrocarbon recovery.

Abstract: The present disclosure describes methods and systems to enhance subsurface models of fractured reservoirs. In particular, the methods and systems described herein incorporate the effects of “dynamic” compressible fractures and, thus, can improve predictions of fractured reservoir performance over time. The methods and systems may utilize predictive algorithms for mechanical and hydraulic stiffness properties of the fracture network that are based at least in part on a database of measurements derived from single fractures.

Abstract: Techniques are described herein that are capable of determining a scope of testing to be performed with respect to machine code based on change(s) that occur with respect to corresponding program code. For instance, behaviors that may be exhibited during execution of the machine code may be determined based on relationships between code elements in the program code, relationships between program data elements that are produced by and/or consumed by the code elements, relationships between the code elements and the program data elements, and/or relationships between the code elements and runtime attributes of the program code. When a change is made to the program code, functionalities are recommended for inclusion in the testing of the machine code. The functionalities are defined to test the machine code with regard to those behaviors that are to be altered by the change that is made to the program code.

Abstract: A debugging pipeline may be developed to create a debugging experience for computer code operating in an execution environment, using a debugging tool outside of the execution environment. A producer can publish a debugging pipeline, configured to link the producer to a consumer (e.g., a debugging tool) by exposing a debugging pipeline interface object to a consumer. The debugging pipeline can implement a set of debugging protocols, comprising: protocol for processing of debugging requests for computer code in at least one of at least two computer languages; a protocol configured for processing of computer code language types in respective signatures without exposing operating system specific constructs; and a protocol for a first debugging pipeline to be isolated from one or more second debugging pipelines. Additionally, a consumer component can provide debugging of the computer code in the execution environment.

Abstract: A method of operating a telemetry system includes receiving an automatically populated set of fields in a schema of an event definition, and providing a response message in an application protocol. The set of fields are automatically populated using a logging library of the telemetry system.

Abstract: A method of operating a telemetry system includes automatically populating a first set of fields in a schema of an event definition using a logging library of the telemetry system, and populating a second set of fields in the schema selected by an event author.

Abstract: A method of operating a telemetry system includes automatically populating a base field of a schema in an event definition using a logging library of the telemetry system for an event of an instrumented application, and automatically populating a conditional field of the schema in the event definition using the logging library in response to a selected condition for the event.

Abstract: A method of operating a telemetry system includes automatically populating a first set of fields in a schema of an event definition using a logging library of the telemetry system, and receiving the set of fields via a request message in an application protocol.

Abstract: A method of estimating at least one mechanical property value of a rock formation in the geologic past. In one embodiment, a correlation model is generated which correlates at least one mechanical property with a porosity value and a composition value relative to a first rock type. An estimation of a past porosity value and a past composition value is then generated for the rock formation at a point of time in the past. A mechanical property value at the point of time in the past is identified in the correlation model based on the estimated past porosity and past composition values.

Abstract: Method and system is described for modeling one or more strength properties of a subsurface volume. The method provides an enhanced process for upscaling to simplify data in a manner that accounts for problems with conventional techniques. The method involves simplifying the petrophysical data and/or layers to provide an upscaling approach that accounts for the influences on the strength properties. The properties may then be utilized to enhance a subsurface model and used to enhance hydrocarbon recovery.

Abstract: Techniques are described herein that are capable of determining a scope of testing to be performed with respect to machine code based on change(s) that occur with respect to corresponding program code. For instance, behaviors that may be exhibited during execution of the machine code may be determined based on relationships between code elements in the program code, relationships between program data elements that are produced by and/or consumed by the code elements, relationships between the code elements and the program data elements, and/or relationships between the code elements and runtime attributes of the program code. When a change is made to the program code, functionalities are recommended for inclusion in the testing of the machine code. The functionalities are defined to test the machine code with regard to those behaviors that are to be altered by the change that is made to the program code.

Abstract: A user can control when data sampling takes place, what data is collected and where in the code the data sampling profiler is invoked. By identifying a section of user code to the profiler, the profiler is instructed to dynamically instrument the identified user code executing in a target application process. The instrumentation invokes the profiler before or after or both before and after the identified section of user code is executed. By identifying an entry point of a component or technology external to the user code, the profiler is instructed to dynamically instrument the external component so that data sampling is logged when the user code calls the entry point of the external component. The data sampling process can be monitored and the sampling rate can be dynamically adjusted.

Abstract: A method of estimating at least one mechanical property value of a rock formation in the geologic past. In one embodiment, a correlation model is generated which correlates at least one mechanical property with a porosity value and a composition value relative to a first rock type. An estimation of a past porosity value and a past composition value is then generated for the rock formation at a point of time in the past. A mechanical property value at the point of time in the past is identified in the correlation model based on the estimated past porosity and past composition values.