The invention relates to a computer implemented method and tool for determining pressure-drop in multiphase pipeline flow where the effective surface roughness, k.sub.eff, of liquid film coated sections of the inner pipeline wall is assumed to be equal to the maximum hydraulic roughness, k.sub.s.sup.max. The maximum hydraulic roughness is further assumed to be proportional to a maximum stable droplet size, d.sub.droplet.sup.max, i.e.: k.sub.eff=k.sub.s.sup.max=K.Math.d.sub.droplet.sup.max, where K is a correlation coefficient. The invention further relates to applying the computer implemented method for designing a pipeline-based fluid transport system for transport of multiphase fluids.

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.

Methods and systems are provided for characterizing a subterranean formation that involve the generation of four 3D geological model of the formation that are updated before and after an enhanced hydrocarbon production process.

A cold plate apparatus that has an outlet plenum leading to an outlet opening includes an outlet transition that connects the outlet opening to the outlet plenum. The outlet transition defines a smoothly curving flow path from a direction along a long dimension of the outlet plenum, which is parallel to a plane defined by the outlet opening, to a direction along a centerline of the outlet opening, which is at an angle from the plane defined by the outlet opening. The outlet transition provides a smooth variation of cross-sectional area from the outlet plenum to the outlet opening.

A water supply simulation method for interlaced system of river and canal system based on groundwater model, includes: S1. constructing simulated water conveyance channel based on first data, and performing attribute definition on water conveyance channels; S2. acquiring initial seepage, evaporation and discharge; S3. performing reverse water demand calculation; S4. performing sequential water supply simulation; S5. acquiring corresponding water head, obtaining current seepage, evaporation, discharge, head-end water demand and water consumption demand of each water conveyance channel based on water head; S6. judging whether current iteration is converged according to water head, if yes, proceeding to S7, otherwise returning to S3 after update; S7. judging whether there is next time period, if yes, returning to S3 after update, otherwise proceeding to S8; and S8. judging whether there is a next stress period, if yes, returning to S3 after update, otherwise outputting the result obtained in S5, and ending.

A method for determining tortuosity, e.g., in an oilfield well includes obtaining a planned trajectory for a hole, and obtaining a first survey of the hole using a sensor deployed into the hole. The first survey includes a first surveyed position at a first depth of the hole and a second surveyed position at a second depth of the hole, and no surveyed positions between the first and second depths. The method further includes simulating a second survey of the hole between the first and second depths using a model. The second survey includes a plurality of simulated positions of the hole between the first and second depths. The method includes determining that the simulated position at the second depth is proximal to the second surveyed position, and visualizing a trajectory of the hole based on the first and second surveys.

A method for modeling fluid flow in a wellbore is provided. Hydraulic fracturing is an effective technique to improve well productivity by forming high permeable pathways for hydrocarbons to flow from the rock formation to the wellbore. Fluid flow for hydraulic fracturing is modeled using separated flow components, including a wellbore component (modeling the wellbore(s)), a perforation component (modeling the perforations(s)), a fracture component (modeling the fracture(s)) and a rock component (modeling the rock). Each respective component may be selected independently from a plurality of available components. Further, the respective components may be coupled to one another only at their interfaces, such as at a wellbore-perforation interface, a perforation-fracture interface, and a fracture-rock interface, for continuity of fluid kinematics and properties (such as pressure and density). In this way, the modeling of the subsurface may be tailored to the respective components in order to effectively predict the fracturing treatment.

An artificial neural network (ANN) system for predicting and optimizing well placement, productivities, and development includes: an ANN; computer hardware for building, training, using, and storing the ANN; and computer software for programming and processing the ANN. The ANN includes an input layer of input nodes representing at least one input parameter, an output layer of output nodes representing at least one output parameter, and at least one hidden layer operatively coupling the input layer to the output layer.

The disclosure presents a technique to generate a fracture model using a differential stress map and model inputs. The technique simulates the fracture model using fracture fronts, initiated at perforations of a perforation stage of a hydraulic fracturing (HF) wellbore. Each fracture front is evaluated using a propagation step of a fracture model process. Using the relative differential stress states, a fracture pattern is composited to the fracture model. At each propagation step, the total energy available from the simulated HF fluid being pumped into the wellbore location is reduced by the amount necessary to generate the computed fractures. Once the remaining energy is reduced to a level where no further fractures can be created, or if a map boundary is encountered, the fracture model process terminates. The generated fracture model can be communicated to update HF job plans, wellbore placements, and other uses of the fracture model.

The invention discloses a full wellbore pressure calculation method, device and computer-readable storage medium for fracturing horizontal wells, includes steps: collect basic parameters, establish fully implicit numerical model of formation flow; solve the full implicit numerical model under an inner boundary condition of a constant gas production rate; calculate wellbore pressure change of each fracturing section of horizontal well; calculate the bottom-hole pressure of each fracture initiation point; repeat steps until the variables converge, the bottom-hole flow pressure and the bottom-hole pressure at each fracture initiation point are obtained at this time step; the wellbore pressure and wellhead casing pressure are calculated at this time step. The method is for predicting the variation law of full wellbore pressure and wellhead casing pressure by using production data in the absence of bottom-hole pressure test data, and has practical value for accurate prediction of production performance of gas reservoir fracturing horizontal wells.