The disclosure presents a technique for determining how downhole material will be distributed among two or more active perforation clusters in a hydraulic fracturing well system. The determination can be conducted during the execution of a treatment stage allowing modifications prior to completion of the treatment stage. The technique utilizes a three-step process where a first step can determine a predictive model of the wellbore, such as subterranean formation properties, wellbore properties, and target goal of the treatment stage. A second step can calibrate for unknown parameters, such as downhole HF fluid pressure at the active perforation clusters and downhole HF fluid flow rate at the perforation clusters. A third step can predict how downhole material will be distributed to the active perforation clusters and fracture clusters. The prediction result can be utilized to modify a pumping plan of the treatment stage to better achieve the targeted goal.

The disclosure presents a technique for determining how downhole material will be distributed among two or more active perforation clusters in a hydraulic fracturing well system. The determination can be conducted during the execution of a treatment stage allowing modifications prior to completion of the treatment stage. The technique utilizes a three-step process where a first step can determine a predictive model of the wellbore, such as subterranean formation properties, wellbore properties, and target goal of the treatment stage. A second step can calibrate for unknown parameters, such as downhole HF fluid pressure at the active perforation clusters and downhole HF fluid flow rate at the perforation clusters. A third step can predict how downhole material will be distributed to the active perforation clusters and fracture clusters. The prediction result can be utilized to modify a pumping plan of the treatment stage to better achieve the targeted goal.

Asphaltene onset pressure of a formation fluid is determined by subjecting the fluid to a plurality of tests where depressurization is conducted at a different depressurization rate for each test while optically monitoring the fluid for asphaltene flocculation. The pressures at which asphaltene flocculation are detected in each test are fit to a curve as a function of depressurization rate, and the curve is extrapolated to a pressure (e.g., 0 psi) to provide the asphaltene onset pressure.

Asphaltene onset pressure of a formation fluid is determined by subjecting the fluid to a plurality of tests where depressurization is conducted at a different depressurization rate for each test while optically monitoring the fluid for asphaltene flocculation. The pressures at which asphaltene flocculation are detected in each test are fit to a curve as a function of depressurization rate, and the curve is extrapolated to a pressure (e.g., 0 psi) to provide the asphaltene onset pressure.

The present invention provides an intelligent geophysical data acquisition system and acquisition method for shale oil and gas optical fiber. A pipe string is arranged in a metal casing, and an external armored optical cable is fixed outside the metal casing; an, internal armored optical cable is fixed outside the pipe string; the external armored optical cable comprises a downhole acoustic sensing optical cable, two multi-mode optical fibers, a strain optical cable and a pressure sensor array, and further comprises horizontal ground acoustic sensing optical cables arranged in the shallow part of the ground according to an orthogonal grid, and artificial seismic source excitation points arranged on the ground according to the orthogonal grid.

A tool including a dispersive spectrometer deployable within a wellbore is provided. The dispersive spectrometer includes a waveguide layer to detect electromagnetic radiation according to wavelength. The dispersive spectrometer also includes a plurality of detector elements disposed along the waveguide layer to detect electromagnetic radiation associated with a portion of the wavelength of the electromagnetic radiation. A method for using the tool in a subterranean application is also provided.

A tool including a dispersive spectrometer deployable within a wellbore is provided. The dispersive spectrometer includes a waveguide layer to detect electromagnetic radiation according to wavelength. The dispersive spectrometer also includes a plurality of detector elements disposed along the waveguide layer to detect electromagnetic radiation associated with a portion of the wavelength of the electromagnetic radiation. A method for using the tool in a subterranean application is also provided.

Systems and methods are provided to facilitate connection of multiple stage completions. A first completion stage is deployed at a wellbore location. Subsequently, the next completion stage is moved downhole into engagement with the first completion stage. The completion stages each have communication lines that are coupled together downhole via movement of the completion stages into engagement.

Systems and methods are provided to facilitate connection of multiple stage completions. A first completion stage is deployed at a wellbore location. Subsequently, the next completion stage is moved downhole into engagement with the first completion stage. The completion stages each have communication lines that are coupled together downhole via movement of the completion stages into engagement.

A hybrid telemetry system includes a plurality of telemetry networks configured to communicate a modulated signal representing digital data along adjoining sections of a pipe string. The plurality of telemetry networks may each be optimized or particularly suitable for the configuration of the pipe string, the well, and/or the environment of the well occurring in each of the adjoining sections. Some of the plurality of telemetry networks may overlap to provide redundancy of the communication of the digital data.