Abstract: Systems and processes for providing multi-directional dialog are provided. An example method includes, at an electronic device with one or more processors, receiving a first natural-language input; determining a first intent based on the first natural-language input, identifying a first dialog flow based on the first intent, outputting a natural-language output associated with the first dialog flow, receiving a second natural-language input; determining whether the second natural-language input satisfies dialog criteria associated with the first dialog flow, and in accordance with a determination that the second natural-language input satisfies the dialog criteria, outputting a second natural-language output associated with the first dialog flow.

Abstract: A claw-back request, received from an accelerator, is issued for an address line. While waiting for a response to the claw-back request, a cast-out push request with a matching address line is received. The cast-out push request is associated with a cache having a modified copy of the address line. A combined-response, associated with the cast-out push request, is received from a bus. Data associated with the modified copy of the address line is received from the cache. A claw-back response, with the data associated with the modified version of the address line, is issued to an accelerator.

Abstract: A multilumen catheter shaft body includes a proximal end segment with a first durometer and a first longitudinal length dimension. A proximal intermediate segment is fixedly joined to a distal end of the proximal end segment and includes a second durometer and a second longitudinal length dimension. A distal intermediate segment is fixedly joined to a distal end of the proximal intermediate segment and includes a third durometer and a third longitudinal length dimension. A distal terminal end segment is fixedly joined to a distal end of the distal intermediate segment and includes a fourth durometer and a fourth longitudinal length dimension. The first durometer is greater than at least the second and third durometers. The fourth durometer is greater than at least the second and third durometers. A plurality of parallel longitudinal lumens extends through the body, providing a structure useful in a cholangioscope or other endoscopic applications.

Abstract: Methods and compositions for mitigating the embedment of proppant into fracture faces in subterranean formations are provided. In some embodiments, the methods comprise: introducing a treatment fluid into a subterranean formation at or above a pressure sufficient to create or enhance one or more fractures in the subterranean formation; introducing an anchoring agent into the subterranean formation to deposit the anchoring agent on a portion of a fracture face in the one or more fractures within the subterranean formation; introducing a first particulate material comprising fine particulates into the subterranean formation to attach to the anchoring agent on the portion of the fracture face, wherein said fine particulates have a mean particle size of up to about 50 ?m; introducing a second particulate material comprising proppant into the one or more fractures in the subterranean formation.

Abstract: Systems and methods for generation of in-situ wellbore, core and cuttings information systems. An image and image derivative based property visualization, analysis and enhancement system is provided, which utilizes various types of image data, such as digital rock physics and physical laboratories, petrographic analysis and the in-situ wellbore imaging and derivative products of image segmentation in the construction of a static earth model.

Abstract: Systems and processes for providing multi-directional dialog are provided. An example method includes, at an electronic device with one or more processors, receiving a first natural-language input; determining a first intent based on the first natural-language input, identifying a first dialog flow based on the first intent, outputting a natural-language output associated with the first dialog flow, receiving a second natural-language input; determining whether the second natural-language input satisfies dialog criteria associated with the first dialog flow, and in accordance with a determination that the second natural-language input satisfies the dialog criteria, outputting a second natural-language output associated with the first dialog flow.

Abstract: A claw-back request, received from an accelerator, is issued for an address line. While waiting for a response to the claw-back request, a cast-out push request with a matching address line is received. The cast-out push request is associated with a cache having a modified copy of the address line. A combined-response, associated with the cast-out push request, is received from a bus. Data associated with the modified copy of the address line is received from the cache. A claw-back response, with the data associated with the modified version of the address line, is issued to an accelerator.

Abstract: Determining characteristics of a formation. At least some of the illustrative embodiments are methods including determining at least one characteristics of a shale formation. The determining may include: collecting optically interacted electromagnetic radiation from a portion of the shale formation; directing a first portion of the optically interacted electromagnetic radiation from the formation to a first multivariate optical element (MOE), the first MOE creates first modified electromagnetic radiation; applying the first modified electromagnetic radiation to a first detector, the first detector creates a first signal; and determining a first characteristic of the shale formation from the first signal.

Abstract: Systems and methods for generation of in-situ wellbore, core and cuttings information systems. An image and image derivative based property visualization, analysis and enhancement system is provided, which utilizes various types of image data, such as digital rock physics and physical laboratories, petrographic analysis and the in-situ wellbore imaging and derivative products of image segmentation in the construction of a static earth model.

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

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

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

Abstract: Determining characteristics of a formation. At least some of the illustrative embodiments are methods including determining at least one characteristics of a shale formation. The determining may include: collecting optically interacted electromagnetic radiation from a portion of the shale formation; directing a first portion of the optically interacted electromagnetic radiation from the formation to a first multivariate optical element (MOE), the first MOE creates first modified electromagnetic radiation; applying the first modified electromagnetic radiation to a first detector, the first detector creates a first signal; and determining a first characteristic of the shale formation from the first signal.

Abstract: Optimizing well planning scenarios. At least some of the illustrating embodiments include: receiving, by a computer system, a complex fracture model that estimates fractures in a subsurface target; applying the complex fracture model to a reservoir model that estimates geological features between the subsurface target and earth's surface; and determining an earth surface well site and a well path from the earth surface well site to the subsurface target based on the complex fracture model and the geological information, wherein the earth surface well site is offset from the subsurface target.

Abstract: Systems and methods for hydraulic fracture characterization using microseismic event data to identify the orientation spacing and dip for subsurface fractures.

Abstract: A method and apparatus for determining a stress field in a subterranean formation include deploying a stress measurement tool on a tubular string, opening at least three fractures in three different radial directions in the subterranean formation, and closing the at least three fractures. The at least three fractures are reopened while measuring stress and strain conditions. From the reopening, a tangential stress component for each of the at least three fractures is determined. From the tangential stress components and radial directions of the at least three fractures, the stress field of the subterranean formation is determined.

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

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

Abstract: Systems and methods for hydraulic fracture characterization using microseismic event data to identify the orientation spacing and dip for subsurface fractures.

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