A standard sample for measuring rock porosity by helium method is disclosed, which includes a cylinder body open above and a cover body matching the cylinder body. The center of the cover body is provided with a vent hole. The cylinder body is filled and tamped with filled sand body so that theoretical porosity in the cylinder body is 5%-10%. The filled sand body includes mixed sand body and quartz cotton. The mixed sand body includes coarse-grained high-purity quartz sand, medium-grained high-purity quartz sand and fine-grained silicon micropowder. By mixing, filling and tamping high-purity quartz sand with different particle sizes, silicon micropowder and quartz cotton, the porosity and permeability of the standard sample are reduced, so that the standard sample is closer to the physical properties of the actual shale geological samples to verify the method or calibrate the instrument for measuring rock porosity with helium method.

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.

The present invention provides a device and a method for measuring fluid saturation in nuclear magnetic resonance (NMR) on-line displacement, the method comprising: measuring a nuclear magnetic resonance (NMR) T2 spectrum under the dead volume filling of the on-line displacement system as displacing phase fluid and the core to be measured as saturated nuclear magnetic detection phase fluid to generate a calibrated T2 spectrum; measuring a nuclear magnetic resonance (NMR) T2 spectrum of a process in which the core to be measured is converted from a saturated displaced phase fluid into a displacing phase fluid to generate a displacement process T2 spectrum; generating the fluid saturation of the on-line displacement system in real time according to the generated calibrated T2 spectrum and the displacement process T2 spectrum. The present invention achieves the purpose of improving measurement precision of fluid saturation in the on-line displacement process.

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.

A system and method for centrifuge fluid production and measurement using resistive cells is provided. The method comprises separating an electrically conducting first fluid and a second fluid within a collection cell having a first and second section, wherein the collection cell has an electrically conductive outer wall and an inner wall having an insulating material disposed thereon. The method provides that the first and second fluids are separated from a solid disposed in the first section into the second section, the second fluid having a specific mass greater than the first fluid. The method further provides measuring, using one or more wires disposed in the second fluid and electrically connected to a resistance measuring unit within the second section, a resistivity change of the second fluid relative to the displacement of the first fluid, and communicating the resistivity change.

A method of estimating a depth of a hydrocarbon-water contact of a hydrocarbon reservoir in a structure. The method may include the steps of analysing one or more samples obtained from the structure to generate a relationship relating resistivity to hydrocarbon-water contact depth, obtaining a resistivity measurement of the hydrocarbon reservoir, and estimating the hydrocarbon-water contact depth from the relationship relating resistivity to hydrocarbon-water contact depth and the resistivity measurement of the hydrocarbon reservoir.

A correcting system includes an acquisition unit, a storage unit, and a correction unit. The acquisition unit acquires information indicating first capture efficiency of a filter for first microscopic particles. The storage unit stores correction data to correct the first capture efficiency to second capture efficiency of the filter for second microscopic particles. The correction unit corrects the first capture efficiency acquired by the acquisition unit to the second capture efficiency based on the correction data.

A correcting system includes an acquisition unit, a storage unit, and a correction unit. The acquisition unit acquires information indicating first capture efficiency of a filter for first microscopic particles. The storage unit stores correction data to correct the first capture efficiency to second capture efficiency of the filter for second microscopic particles. The correction unit corrects the first capture efficiency acquired by the acquisition unit to the second capture efficiency based on the correction data.