Examples described herein provide for modeling acid flow for acid stimulation of a formation. An example method includes receiving data about the acid stimulation. The method further includes modeling, by applying the data about the acid stimulation to a model, a wormhole velocity of an acid injected into the formation during the acid stimulation, wherein the wormhole velocity is a function of a Darcy velocity of the acid. The method further includes determining whether the wormhole velocity satisfies a wormhole velocity threshold. The method further includes, responsive to determining that the wormhole velocity fails to satisfy the wormhole velocity threshold, modifying a stimulation parameter to adjust the wormhole velocity of the acid. The method further includes performing the acid stimulation based at least in part on the modified stimulation parameter.

An estimated gas leak flow rate can be determined using a teaching set of concentration profiles, a regression model implemented by a machine-learning subsystem, and a subset of attributes measured within an environment. The teaching set of concentration profiles can include gas flow rates associated with relevant attributes. The regression model can be transformed into a gas leak flow regression model via the machine-learning subsystem using the teaching set. The subset of attributes measured within the environment can be applied to the gas leak flow regression model to determine other attributes absent from the subset of attributes and an estimated gas flow rate for the environment. A gas leak attenuation action can be performed in response to the estimated gas flow rate.

A sensor node system for mapping hydraulic fractures may include a localization system that identifies location information of the sensor node device with respect to an area of interest in a rock formation. The location information may include various magnetization parameters indicative of various signal strengths surrounding the sensor node device. The sensor node device may include a transceiver that exchanges signals with a base station and at least one other sensor node device. The transceiver establishes a communication link between the base station and the sensor node device. The transceiver may monitor at least one other communication link between the at least one other sensor node device and the base station. The sensor node device may include a processor that identifies distance information based on the location information and a predetermined number of signals associated to the various signal strengths surrounding the sensor node device.

The systems and method described in this specification relate to a method for determining a residual oil saturation of a reservoir. The method includes obtaining a plurality of rock samples from the reservoir; determining a permeability of each of the rock samples; measuring a fluid viscosity of oil in the reservoir; estimating a location-specific permeability of the reservoir across the reservoir based on the permeability of each of the rock samples; determining a location-specific displacing velocity of the reservoir based on a function of the location-specific permeability and the fluid viscosity of the oil; determining the residual oil saturation of the reservoir based on the location-specific displacing velocity using Franklin's equation; and predicting a recovery of the oil from the reservoir using the residual oil saturation in a computational model of the reservoir.

Methods, systems, and non-transitory computer readable media for estimating well interference on a target well from other potential wells in a subsurface volume of interest are disclosed. Exemplary implementations may include: obtaining well implementation data for the target well and the other potential wells; obtaining estimated reservoir volumes as a function of position; generating well overlap between the target well and the other potential wells; generating extraction interference probabilities; generating a representation of a well layout as a function of position in the subsurface volume of interest; and displaying the representation.

The invention presents a methodology for evaluating the drainage efficiency of the proposed drainage mesh, by identifying poorly drained regions for mesh optimization and/or implementation of complementary projects, in addition to qualitatively evaluating the drainage effect of a field with different number of wells and units and, finally, comparatively evaluating the drainage quality from different reservoirs, thus observing opportunities for optimizing production management, such as activating different intelligent completion valves, for example. To achieve this objective, it applies a set of filters to the mobile HPHISO map in order to identify the regions that have the greatest potential to be explored and that will bring greater recovery gains for a given oil field.

The present disclosure relates to a method for stimulating a subterranean formation that includes performing an initial stimulation in a wellbore positioned within the subterranean formation to place a designed volume of a first proppant in fractures, determining a near wellbore fracture width of the fractures, determining an unpropped fracture length of the fractures based on a rock bending model, determining an unpropped fracture volume based on the unpropped fracture length and near wellbore width of the fractures and performing a second stimulation treatment to place a proppant in fractures in an amount equal to the unpropped fracture volume. This operation allows to restore the conductivity of fracture in the damaged zone.

The present disclosure belongs to the field of petroleum engineering, and specifically relates to a subsea Christmas tree re-prediction method integrating Kalman filter and Bayesian network. The subsea Christmas tree re-prediction method integrating Kalman filter and Bayesian network includes three steps: digital twin model establishment, degradation process re-prediction model establishment, and remaining useful life calculation model establishment. The subsea Christmas tree re-prediction system integrating Kalman filter and Bayesian network includes a subsea distribution unit information acquisition subsystem mounted on an subsea distribution unit, a subsea control module information acquisition subsystem mounted on a subsea control module, a subsea valve bank information acquisition subsystem mounted on a subsea valve bank, a wellhead mechanical module information acquisition subsystem mounted on a wellhead mechanical module, a subsea environmental information acquisition module mounted on a subsea control module, and a subsea Christmas tree digital twin subsystem mounted in an overwater control station.

The present disclosure provides an edge and bottom water invasion simulation apparatus and method, a storage medium, and a product. A controller controls an inert gas to be injected into a first intermediate container, and stops the injection. The controller controls formation water to be injected into the first intermediate container, and stops the injection. The controller controls the first intermediate container to be communicated with a core holder, and adjusts a pressure of a back pressure valve, so that the formation water enters a core to simulate edge and bottom water invasion. In the present disclosure, by adding the inert gas and the formation water to the intermediate container, an infinite edge and bottom water with sufficient energy at an early stage of a water invasion and a limited edge and bottom water with lower energy at a later stage of the water invasion can be effectively simulated.

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.