A method includes determining reservoir rock and fluid characteristics of a reservoir rock and, based on the reservoir rock and fluid characteristics of the reservoir rock, selecting a core. The method also includes selecting a first surfactant and selecting a second surfactant. In addition, the method includes performing a water block mitigation test using the selected core, the first surfactant and the second surfactant and performing a proppant phase trapping mitigation test using the selected core, the first surfactant and the second surfactant.

A sample of a first aqueous liquid phase is drawn from a first one of a plurality of separation vessels in response to determining that a first separation operation in the first separation vessel has completed. First aqueous liquid phase sample data is obtained by analyzing the first aqueous liquid phase sample with at least one sensor. The first aqueous liquid phase sample data is transmitted to an external multiphase flow meter (MPFM) to calibrate, control, or optimize an operation of the MPFM. A sample of a second aqueous liquid phase is drawn from a second one of the plurality of separation vessels in response to determining that a second separation operation in the second separation vessel has completed. Second aqueous liquid phase sample data is obtained by analyzing the second aqueous liquid phase sample with the at least one sensor. The second aqueous liquid phase sample data is transmitted to the external multiphase flow meter. The first separation operation in the first separation vessel and the second separation operation in the second separation vessel are concurrent.

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.

A method for operating a kerogen-rich unconventional gas reservoir characterized by there being multiple hydraulically-fractured wells drilled thereinto comprises: recovering a methane-containing gas from a first hydraulically-fractured well drilled into the gas reservoir, steam-methane reforming the recovered methane-containing gas to yield a hydrogen gas and an inorganic carbon-containing gas, injecting at least a portion of the hydrogen gas into a second hydraulically-fractured well drilled into the gas reservoir, and injecting at least a portion of the inorganic carbon-containing gas into a third hydraulically-fractured well drilled into the gas reservoir.

An example logging tool includes an injection system, a detection system, and an electric control and processing system. The injection system includes a gas source, and is configured to inject a first gas from the gas source into a region of a subterranean formation. The detection system includes a gas detection chamber and one or more sensors disposed in the gas detection chamber, and is configured to receive, in the gas detection chamber, a sample from the region of the subterranean formation, and generate, using the one or more sensors, sensor measurements of the sample, The electronic control and processing system includes one or more processors, and is configured to determine one or more characteristics of the subterranean formation based on the sensor measurements.

A method and system are described for creating subsurface models that involve the use of isomorphic reversible scanning curve for simulating hysteresis in reservoir simulators. The method includes constructing a subsurface model for a subsurface region and using the subsurface model in simulations and in hydrocarbon operations, such as hydrocarbon exploration, hydrocarbon development, and/or hydrocarbon production.

A system and method for evaluating a wellbore involves drawing fluid from a surrounding formation into an isolated portion of the wellbore, collecting the fluid in the isolated portion, and directing the sampled fluid to surge tanks on surface through a string of coiled tubing. The system and method includes measuring fluid properties, such as density and viscosity; and observing fluid flow characteristics, such as the fluid pressure, the fluid flowrate, and changes in the fluid flowrate. Based on the measured fluid properties and observed characteristics a determination is made if the wellbore is a candidate for a drill stem test.

A formation test probe and a formation test system and method for implementing a self-drilling probe are disclosed. In some embodiments, a test probe includes a body having a channel therethrough to a frontside port, and further includes drill-in tubing disposed within the channel and having a front tip that is extensible from the frontside port. An exciter is disposed within the body in contact with the drill-in tubing and operably configured to induce resonant vibration in the drill-in tubing during a drill-in phase of a formation test cycle.

A tubular defines a central flow passage. A camera has an aperture and attached to an outer surface of the tubular with the aperture oriented away from the outer surface of the tubular. A lost circulation media reservoir is circumferentially surrounding at least a portion of the outer surface of the tubular. The lost circulation media reservoir is adjacent to the camera. The lost circulation media reservoir includes actuable gates along a periphery of the lost circulation media reservoir. A trigger is communicably coupled with the actuable gates and configured to actuate the actuable gates.

A method for operating a kerogen-rich unconventional gas reservoir characterized by there being multiple hydraulically-fractured wells drilled thereinto comprises: recovering a methane-containing gas from a first hydraulically-fractured well drilled into the gas reservoir, steam-methane reforming the recovered methane-containing gas to yield a hydrogen gas and an inorganic carbon-containing gas, injecting at least a portion of the hydrogen gas into a second hydraulically-fractured well drilled into the gas reservoir, and injecting at least a portion of the inorganic carbon-containing gas into a third hydraulically-fractured well drilled into the gas reservoir.