Methods and systems for determining fracture and matrix permeability of a subsurface formation. The system includes two upstream reservoirs and two downstream reservoirs, and a sample cell connecting to the reservoirs with valves. The sample cell has a confining pressure (CF) from a fluid. A horizontal plug sample with sleeve is placed in a measurement cell with the confining fluid (CF). A pressure gauge is connected to the small upstream reservoir, and a pressure gauge is connected to the small downstream reservoir. The results provide two sets of effective-stress-dependent permeability values (including fracture permeability and matrix permeability, respectively) for characterizing the reservoir properties.

Embodiments herein relate to fuel monitoring systems and related methods. In an embodiment, a fuel monitoring system for a vehicle is included having a fuel filter sensor device configured to generate data reflecting a filter restriction value of a fuel filter, a geolocation circuit configured to generate or receive geolocation data, and a system control circuit configured to evaluate the sensor data to determine changes in the filter restriction value. The control circuit can receive fuel level data, cross-reference geolocation data and fuel level data to identify refueling locations utilized, and correlate refueling locations with subsequent changes in filter restriction to identify an effect of specific refueling locations on fuel filter loading. In some embodiments, a refueling guidance system for a vehicle is included that can provide route and/or refueling site recommendations based on fuel filter loading rate data. Other embodiments are also included herein.

Methods and systems for increasing normalized production rate of an oil and gas reservoir by optimizing a pressure drawdown of a subsurface formation are disclosed. The methods include determining permeability of the subsurface formation as a function of effective stresses, determining a stress sensitivity factor for the core sample, upscaling the sensitive stress factor, determining the optimum pressure drawdown for the subsurface formation, and controlling the pressure drawdown in a field operation such that it does not exceed the optimum pressure drawdown for the subsurface formation.

A method can include receiving porosimetry data for a range of pressures that spans a transition zone defined at least in part by a high-pressure end of a first pressure zone and a low-pressure end of a second pressure zone; detecting at least one artifact in the transition zone; computing accuracy information for the highpressure end of a first pressure zone and the low-pressure end of a second pressure zone; computing a pressure-volume adjustment based at least in part on the accuracy information; and outputting a pressure-volume relationship in the transition zone based at least in part on the pressure-volume adjustment.

Systems and methods for measuring dynamic hydraulic conductivity and permeability associated with a cell layer are disclosed. Some systems include a microfluidic device, one or more working-fluid reservoirs, and one or more fluid-resistance element. The microfluidic device includes a first microchannel, a second microchannel, and a barrier therebetween. The barrier includes a cell layer adhered thereto. The working fluids are delivered to the microfluidic device. The fluid-resistance elements are coupled to one or more of the fluid paths and provide fluidic resistance to cause a pressure drop across the fluid-resistance elements. Mass transfer occurs between the first microchannel and the second microchannel, which is indicative of the hydraulic conductivity and/or dynamic permeability associated with the cells.

The invention relates to the technical field of oilfield exploration, and discloses a 4D quantitative and intelligent diagnosis method and system for spatio-temporal evolution of oil-gas reservoir damage types and extent. The method includes: determining a characteristic parameter characterizing reservoir damage by each of a plurality of factors based on a spatio-temporal evolution simulation equation of reservoir damage by each of the plurality of factors; and determining an effective characteristic parameter characterizing the damage extent of the reservoir based on the characteristic parameter characterizing reservoir damage rby each of the plurality of factors. The invention can quantitatively simulate the characteristic parameters of reservoir damage caused by the various factors and a total characteristic parameter of the reservoir damage. Therefore for a well without reservoir damage, performing quantitative prediction of reservoir damage and spatio-temporal deduction of damage laws is of scientific guidance significance for preventing reservoir damage, and formulating development plans for oil pools and subsequent well stimulation measures, and for a well with reservoir damage, also performing quantitative diagnosis of reservoir damage and spatio-temporal deduction of damage laws achieves optimal design of a declogging measure and improvement or restoration of oil-gas well production and water well injection capacity.

The present technology generally relates to a porous medium parameter measurement device. The porous medium parameter measurement device comprises: a liquid permeable portion comprising a fluid permeable component and a polymer swellable solution; and comprises a gas permeable portion comprising a gas permeable component. The liquid permeable portion is in operative communication with the gas permeable portion through the gas permeable component; and the gas permeable component acts to purge gases from the liquid permeable component and the polymer swellable solution.

Methods, apparatus, and systems for testing a hydrogen permeability of a non-metallic pipe are provided. In one aspect, an apparatus for testing a hydrogen permeability of a non-metallic pipe includes: pipe sealing pieces, a test cylinder, a high pressure gas source, a gas exhaust tube, a vacuum pump, and a pressure sensor. A plurality of circumferential reinforcement pieces are disposed on a circumferential inner wall surface of a cylindrical body of the test cylinder to be in contact with an outer surface of a to-be-tested pipe placed in the test cylinder and perform circumferential reinforcement on the to-be-tested pipe.

Defect detection systems include at least one nozzle for delivering a CO.sub.2 particulate fluid to an inlet end of a plugged honeycomb body. Defects in the honeycomb, if any, are determined by monitoring CO.sub.2 particulate flow at the outlet end of the honeycomb body. Methods for detecting defects in plugged honeycomb bodies are also disclosed.

An integrity testing method for a porous medium in a housing having an interior separated by the medium into upstream and downstream portions, an inlet and an outlet communicating, respectively, with the upstream and downstream portions, the outlet connected to a closeable conduit, comprises filling the downstream portion and conduit with liquid, draining the upstream portion and filling it with gas while retaining liquid in the downstream portion, connecting a gas-filled testing volume to the downstream portion, maintaining gas pressure of a predetermined testing differential pressure in the upstream portion, the differential pressure being lower than a predefined bubble point of the medium, determining the pressure in the testing volume, the testing volume selected such that, when a medium is tested having a bubble point corresponding to the predefined bubble point, a pressure increase within the testing volume of about 100 mbar or more is obtained within 10 minutes.