Ifp Energies Nouvelles

Institut Francais Du Pe'trole

Institut Francias Du Petrole

Bernard Bourbiaux

Sylvain Sarda

Marie-Christine Cacas

Andre Fourno

Benjamin Braconnier

Quang Long Nguyen

André Fourno

Elena Sanz

Isabelle Durand

Christophe Preux

Didier Yu Ding

Emmanuel Manceau

Matthieu Delorme

Vivien Esnault

Jean-Francois Lecomte

Rémy Basquet

Omar Gassara

Lahcen Nabzar

Laurent Jeannin

Sébastien Lacroix

Frederic Douarche

Luca Cosentino

Jean-Claude Sabathier

Marie Marsiglia

Habiba Boulharts

Vlasios Leontidis

Daniela Bauer

Philippe Delaplace

The present invention relates to a system of heat exchange between a building () and the Earth's subsurface (), comprising a closed loop with at least one pipe () installed in said subsurface () for heat exchange with subsurface (), and connected by connecting pipes () to at least one pipe () installed in said building () for heat exchange with building (), the closed loop comprising a circulation pump (P) for circulating a fluid through said closed loop, and the fluid comprising capsules containing phase change materials. The invention also relates to a method for cooling or heating a building () from the heat exchange system between a building () and the Earth's subsurface ().

System for heat exchange between a building and the earth's sub-soil comprising the circulation of phase change materials in a closed circuit

The invention relates to a method for recovery of hydrocarbons in a geological reservoir by injection of a low-salinity aqueous solution. A representative model of the evolution of the flow parameters as a function of the aqueous solution salinity is calibrated by use of laboratory measurements performed on a rock sample from the reservoir for at least two salinity values. Then, by use of a flow simulator including the calibrated model, the injection of aqueous solutions into the sample is simulated, with and without capillary effects, for at least the two salinity values with a microscopic residual oil saturation being determined for each salinity value. Then, from the flow simulator including the calibrated model and the microscopic residual oil saturation values, a reservoir development scheme is determined with hydrocarbons of the reservoir being exploited according to the development scheme.

Method for recovery of hydrocarbons in a geological reservoir by low-salinity water flooding

The present invention relates to a method for optimizing a fluid deposit traversed by a fracture network. For this method, the deposit is discretized in a meshed representation, a 'dual medium' approach is used, and the exchange flows are determined between the meshes, together with corrective factors. The corrective factors are dependent on the initial pressure and the minimum production pressure of the deposit. The fluid flows in the deposit are simulated by means of these flows and these corrective factors.

Method for the development of a fluid deposit traversed by fractures by means of a flow simulation based on an exchange flow and a corrective factor

A method for developing a hydrocarbon reservoir by injecting a gas in the form of foam, comprising a step of determining a foam displacement model, which is a function of an optimal gas mobility reduction factor and of at least one water saturation-dependent interpolation function. The optimal gas mobility reduction factor is determined and constants of the water saturation-related interpolation function are calibrated from a plurality of apparent viscosity measurements for various foam quality values, and by use of a lamella model allowing which relates the lamella density as a function of the water saturation. The invention has an application to petroleum exploration and development.

Method for developing a hydrocarbon reservoir by injecting a gas in the form of foam

The invention is a method for optimizing working (EXP) of a deposit of fluid traversed by a network of fractures that involves determining the transitory exchange terms between matrix blocks and fractures (FFA, FFN), for any type of available information (INFO) concerning the network of fractures, regardless of the level of knowledge of the fractured environment.

Method for optimizing the working of a deposit of fluid by taking into account a geological and transitory exchange term between matrix blocks and fractures

The invention is a method for operating a hydrocarbon deposit by injection of gas in foam form, comprising determining a model of displacement of the foam which is a function of an optimal mobility reduction factor of the gas and at least one interpolation function dependent on a parameter and constants to be calibrated. The mobility reduction factor of the gas is determined and the constants of at least one interpolation function are calibrated from experimental measurements comprising injections of gas in non-foaming form and in foam form into a sample of the deposit for different values of the parameter relative to the function being considered. Measurements of headloss corresponding to each value of the parameter of the interpolation function are considered. The calibration of the constants is performed interpolation function by interpolation function.

Method for operating a hydrocarbon deposit by injection of a gas in foam form

Method for exploiting a fluid within an underground formation comprising a layer traversed by a fracture network and a well. From property measurements relative to the layer, the fracture network is characterized by statistical parameters and a discrete fracture network model is constructed. For each well, three simplification zones surrounding the well are defined. From the statistical parameters, an equivalent permeability tensor and a parameter characterizing the orientation and the vertical continuity of the fractures are determined for each zone. For each zone, a simplification of the discrete fracture network model is determined as a function of the zone, the equivalent permeability tensor and the value of the parameter. An optimum exploitation scheme is defined for the formation fluid from the simplified fracture network model and a flow simulator.

Method for characterizing the fracture network of a fractured reservoir and method for exploiting it

The present invention relates to a method for enhanced hydrocarbon recovery in an underground reservoir rock comprising injecting an aqueous conditioning solution containing an alkaline agent, wherein the in-situ effects of the injection are determined by means of a flow simulation on a reservoir model discretized in cells, by taking into account the transport of the alkaline agent and without taking into account the transport of species referred to as intermediate species that result from the injection of the principal agent in aqueous solution, the intermediate species concentrations being determined analytically in each cell.

Enhanced hydrocarbon recovery method comprising optimizing the injection of an aqueous conditioning solution

The invention is a method of evaluating a recovery potential for hydrocarbons contained in a fractured reservoir, using an enhanced recovery technique. Characteristic reservoir data, data obtained from well test results and data relative to the development conditions are acquired. A pressure gradient related to the flow of a fluid injected to improve recovery is then estimated from the previously acquired data. A recovery coefficient is calculated for the hydrocarbons initially in place in matrix blocks by estimating water saturation for a state of equilibrium of the matrix blocks. Finally, the oil recovery time under the effect of the fluid circulation in fractures is estimated by determining the required for the matrix blocks to change from the initial state to a state of equilibrium.

Method of evaluating and selecting an enhanced oil recovery strategy for fractured reservoirs

The invention is a method for constructing a representation of a fluid reservoir traversed by a fracture network and by at least one well. The reservoir is discretized into a set of grid cells and the fractures are characterized by statistical parameters from observations of the reservoir. An equivalent permeability tensor and an average fracture opening is constructed from an image representative of the fracture network delimiting porous blocks and fractures is then deduced from the statistical parameters. A first elliptical boundary zone centered on the well and at least a second elliptical boundary zone centered on the well which form an elliptical ring with the elliptical boundary of the first zone are defined around the well. The image representative of the fracture network is simplified in a different manner for each of the zones which is used to construct the representation of the fluid reservoir.

Method for characterizing the fracture network of a fractured reservoir and method for developing it

A method of modelling a fractured reservoir having application for petroleum reservoir development is disclosed utilizing a set of several families of equivalent blocks of regular shapes and sizes. The fractured reservoir is modelled by a complex porous medium made up of irregular blocks. A function defining the progress of an imbibition front within these blocks, whose derivative A'(X) is calculated, is determined. A function defining the progress of an imbibition front within regular equivalent blocks, whose derivative A&#x2032;eq(X) is calculated, is then determined. This derivative, which constitutes at least two line segments with distinct slopes, depends on the dimensions of the equivalent blocks. Finally, the dimensions of the equivalent blocks are obtained by adjusting the two derivatives A&#x2032;eq(X) and A&#x2032;(X).

Method of modelling a porous geologic medium traversed by a network of fractures

A method for optimizing the development of a fluid reservoir by accounting for a transient exchange term between porous blocks and fractures. The reservoir is discretized into a set of grid cells and an image representative of the fracture network delimiting porous blocks and fractures is associated with each cell. A transient exchange flow occurring between the porous blocks and the fractures is then determined at each cell by processing the image representative of the fracture network. Fluid flows in the reservoir are simulated by a flow simulator and an exchange flow and development of the reservoir is optimized by the simulation.

Method of optimizing the development of a fluid reservoir by taking into account a geologic and transient exchange term between matrix blocks and fractures

A method for optimizing the development of a fractured hydrocarbon reservoir wherein the network permeability is determined using a reliable compromise between numerical and analytical methods which has application to oil reservoir development. The reservoir is discretized into a set of grid cells and a geometrical description of the fracture network in each cell is elaborated. A connectivity index is then deduced within each cell for the fractures. The permeability of the fracture network of the cells whose connectivity index is above a first threshold is determined and a zero permeability value is assigned in the other cells. Other thresholds can be determined so as to choose between a numerical method and an analytical method to determine the permeability. These permeabilities are exploited in a flow simulator so as to optimize the development of the reservoir.

Method of estimating the permeability of a fracture network from a connectivity analysis

A method is disclosed for modelling low or high compressibility fluid flows in a multilayer porous medium crossed by a network of fractures of given geometry, unevenly distributed in the medium, some of the fractures communicating with one another. Each fractured layer is defined by means of a grid pattern comprising fracture grid cells centered on nodes either at the fracture intersections or at the fracture ends. Each node is associated with a matrix block including all the points closer thereto than to neighboring nodes, and the local flows between each fracture grid cell and the associated matrix volume are calculated in a pseudosteady state. A modelling equation whose form is similar to the diffusion equation solved in conventional cases (low compressibility fluids) allows accounting for the compressibility of the fluids. The direct flows between the fracture grid cells and the direct flows between the matrix volumes through the common edges of the grid cells are determined, and the interactions between the pressure and flow rate variations that can be observed in at least one well through the medium are simulated.

Method for modelling fluid flows in a multilayer porous medium crossed by an unevenly distributed fracture network

A method for simulating compositional and/or multiphase transfers between the porous matrix and the fractures of a fractured multilayer porous medium, which are respectively saturated by a distinct liquid phase and gas phase. The method comprises constructing a geologic model representative of the networks of natural fractures of the medium and converting this geologic model into an equivalent double porosity model. Diffusion of the gas phase between the fractures and the matrix is modelled considering that a gas-liquid front exhibiting a quasi-static equilibrium at the interfaces is established from an initial time and progresses at a velocity controlled by the diffusion transfers within each phase. The transfers involve the difference between the concentration within the phase and the concentration of equilibrium between the two phases, as well as a variable exchange distance expressed as a function of the matrix saturation.

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Rueil Malmaison, France

Bernard Bourbiaux