A process system includes a process module, an upstream pipe, a downstream pipe, an inlet pipe with an inlet isolation valve, an outlet pipe with a discharge isolation valve, a bypass with a bypass isolation valve, and a drainage line with a valve. The process module has an inlet, an outlet, and a drainage outlet. The inlet pipe fluidically connects the inlet of the process module to the upstream pipe. The outlet pipe fluidically connects the outlet of the process module to the downstream pipe. The bypass fluidly connects the upstream pipe and the downstream pipe via the bypass isolation valve. The drainage line fluidly connects the drainage outlet of the process module to the downstream pipe via the valve.

A submersible pump assembly includes a pump, a motor, and a seal section connected between. A shaft passage in the seal section has an outboard end that is open to the pump intake and an inboard end that is in fluid communication with motor lubricant in the motor. A drive shaft extends axially within the shaft passage. An outboard bearing at the outboard end of the shaft passage receives the shaft to provide radial support. An inboard bearing at the inboard end of the shaft passage receives the shaft to provide radial support. A shaft seal in the shaft passage receives and seals around the shaft. The shaft seal is located between the outboard bearing and the inboard bearing and seals motor lubricant in the shaft passage from well fluid in the shaft passage.

Systems and methods corresponding with improved wellfield management are provided. In some examples, the system may initiate a step drawdown test of well efficiency to determine a cause of a decreased discharge rate of the wellfield site. The system may alter pumping of the wellfield site based on the step drawdown test, wherein a command signal is transmitted via a SCADA system to the wellfield site.

Methods and systems for supply of fuel for a turbine-driven fracturing pump system used in hydraulic fracturing may be configured to identify when the supply pressure of primary fuel to a plurality of gas turbine engines of a plurality of hydraulic fracturing units falls below a set point, identify a gas turbine engine of the fleet of hydraulic fracturing units operating on primary fuel with highest amount of secondary fuel available, and to selectively transfer the gas turbine engine operating on primary fuel with the highest amount of secondary fuel from primary fuel operation to secondary fuel operation. Some methods and systems may be configured to transfer all gas turbine engines to secondary fuel operation and individually and/or sequentially restore operation to primary fuel operation and/or to manage primary fuel operation and/or secondary fuel operation for portions of the plurality of gas turbine engines.

Methods and systems for supply of fuel for a turbine-driven fracturing pump system used in hydraulic fracturing may be configured to identify when the supply pressure of primary fuel to a plurality of gas turbine engines of a plurality of hydraulic fracturing units falls below a set point, identify a gas turbine engine of the fleet of hydraulic fracturing units operating on primary fuel with highest amount of secondary fuel available, and to selectively transfer the gas turbine engine operating on primary fuel with the highest amount of secondary fuel from primary fuel operation to secondary fuel operation. Some methods and systems may be configured to transfer all gas turbine engines to secondary fuel operation and individually and/or sequentially restore operation to primary fuel operation and/or to manage primary fuel operation and/or secondary fuel operation for portions of the plurality of gas turbine engines.

A method includes comparing and displaying prospect and existing well data on a graphical user interface. The method includes displaying a close-ology map portion that provides a visual indicator of existing well locations relative to a prospect well. The system displays the close-ology map portion along with all other partnership details on a partnership details page. All relevant information is displayed or accessible via the partnership details page. Data relating to the existing well locations is accessed and displayed to a user of the graphical user interface and can be filtered and compared easily to the prospect well.

Differential equations defining physics of a reservoir are modeled as a neural network. Measured data for the reservoir is used as boundary condition to calculate the different equation parameters. The result is a neural ordinary differential equation network that models reservoir characteristics (e.g., inter-well connectivities, response times for injection wells and production wells) using physics that are encoded into the network. The neural ordinary differential equation network provides a solution for the reservoir that is constrained by the physics of the reservoir.

A method of optimizing production of a hydrocarbon-containing reservoir by measuring low-frequency Distributed Acoustic Sensing (LFDAS) data in the well during a time period of constant flow and during a time period of no flow and during a time period of perturbation of flow and simultaneously measuring Distributed Temperature Sensing (DTS) data from the well during a time period of constant flow and during a time period of no flow and during a time period of perturbation of flow. An initial model of reservoir flow is provided using the LFDAS and DTS data; the LFDAS and DTS data inverted using Markov chain Monte Carlo method to provide an optimized reservoir model, and that optimized profile utilized to manage hydrocarbon production from the well and other asset wells.

A method of optimizing production of a hydrocarbon-containing reservoir by measuring low-frequency Distributed Acoustic Sensing (LFDAS) data in the well during a time period of constant flow and during a time period of no flow and during a time period of perturbation of flow and simultaneously measuring Distributed Temperature Sensing (DTS) data from the well during a time period of constant flow and during a time period of no flow and during a time period of perturbation of flow. An initial model of reservoir flow is provided using the LFDAS and DTS data; the LFDAS and DTS data inverted using Markov chain Monte Carlo method to provide an optimized reservoir model, and that optimized profile utilized to manage hydrocarbon production from the well and other asset wells.

The invention discloses a method for improving a recovery ratio of a braided well pattern of a hugely thick or multi-layer oil and gas reservoir, which improves the recovery ratio of the hugely thick or multi-layer oil and gas reservoir by designing the braided well pattern. The braided well pattern is designed through the following method: dividing a cubic development unit of the oil and gas reservoir; measuring a physical property parameter of the cubic development unit; calculating a well pattern design parameter according to the physical property parameter, wherein the well pattern design parameter includes a number of wells and a well bore track; and drilling a large-displacement horizontal well according to the well pattern design parameter. The step of dividing the cubic development unit of the oil and gas reservoir specifically includes: obtaining a boundary of the oil and gas reservoir through seismic volume data; obtaining a main layer series of development of the oil and gas reservoir according to a geological model established on the basis of a prospecting parameter; and establishing a cube with a largest volume in the main layer series of development, wherein the cube is the cubic development unit. The invention can effectively improve the recovery ratio of the hugely thick or multi-layer oil and gas reservoir.