Abstract: A Flogrid Simulation Gridding Program includes a Flogrid structured gridder. The structured gridder includes a structured areal gridder and a block gridder. The structured areal gridder will build an areal grid on an uppermost horizon of an earth formation by performing the following steps: (1) building a boundary enclosing one or more fault intersection lines on the horizon, and building a triangulation that absorbs the boundary and the faults; (2) building a vector field on the triangulation; (3) building a web of control lines and additional lines inside the boundary which have a direction that corresponds to the direction of the vector field on the triangulation, thereby producing an areal grid; and (4) post-processing the areal grid so that the control lines and additional lines are equi-spaced or smoothly distributed. The block gridder of the structured gridder will drop coordinate lines down from the nodes of the areal grid to complete the construction of a three dimensional structured grid.

Abstract: A method and device are provided for monitoring the interfaces between and other physical characteristics of fluids in the pore spaces of an underground formation. The device includes a sleeve around which, when in use, an annular measuring chamber is formed which is in fluid communication with the pore spaces of the surrounding formation but which is hydraulically isolated from other parts of the wellbore of a production or other well in which the device is mounted. An array of capacitor or other sensors is mounted in the measuring chamber for measuring the interfaces between, or other physical characteristics of, the fluids in the measuring chamber.

Abstract: Method for determining, from a 3D image, the values of hydraulic parameters such as the large-scale equivalent permeability, the permeability of blocks and the matrix-fracture exchange coefficient .alpha. of a fractured porous medium such as a geologic formation. The method mainly comprises discretization of the medium by means of a grid pattern and fast and approximate solution, in this grid pattern, of equations modelling diffusion of the fluids in the medium, determination of the variation with time of a large-scale transfer function (f(t), f(s)) characterizing the fluid flows from the matrix to the fractures, by simulation of the movement of particles performing random walks in continuous time on said grid pattern and suitable processing of a state function (.epsilon.(.tau.)) indicative of the presence thereof either in the matrix or in a fracture. The method can be applied for large-scale modelling of fractured oil reservoirs allowing well test interpretation.

Abstract: Methods and processes are claimed for optimal design of hydraulic fracturing jobs, and in particular, methods and processes for selecting the optimal amount of proppant-carrying fluid to be pumped into the fracture (which is a crucial parameter in hydraulic fracturing) wherein these design parameters are obtained, ultimately from a priori formation/rock parameters, from pressure-decline data obtained during both linear and radial flow regimes, and by analogy with a related problem in heat transfer, in addition the claimed methods and processes also include redundant verification means.

Abstract: Methods and apparatus for estimating values for formation parameters such as permeability, relative permeability, and skin factors for a plurality of locations in the formation are provided. Fluid is forced into a capped borehole at a measured rate, and a borehole logging tool is run in the borehole to measure indications of pressure and conductivity. Estimates of the parameters and the measured fluid flow rate(s) into the formation are used in conjunction with a jointly inverted pressure transient model and saturation-conductivity model in order to compute indications of expected pressure and indications of expected conductivity-related profiles as a function of depth and time. The expected pressures and expected conductivity related profile indications are then compared to the pressures and conductivity indications measured by the borehole logging tool, and an iterated comparison between the computed values and the measured values is used to provide determinations of the formation parameters.

Abstract: An apparatus and method are disclosed for obtaining samples of pristine formation or formation fluid, using a work string designed for performing other downhole work such as drilling, workover operations, or re-entry operations. An extendable element extends against the formation wall to obtain the pristine formation or fluid sample. While the test tool is in standby condition, the extendable element is withdrawn within the work string, protected by other structure from damage during operation of the work string. The apparatus is used to sense or sample downhole conditions while using a work string, and the measurements or samples taken can be used to adjust working fluid properties without withdrawing the work string from the bore hole. When the extendable element is a packer, the apparatus can be used to prevent a kick from reaching the surface, adjust the density of the drilling fluid, and thereafter continuing use of the work string.

Abstract: Method for determining the equivalent fracture permeability of a fracture network in a subsurface multi-layered medium from a known representation of this network. The equivalent fracture permeability of a fractured network in a subsurface multi-layered medium, is determined by discretizing with a specific procedure each fracture (F) of the fracture network in fracture elements (R) (such as rectangles for example) and defining nodes N representing interconnected fracture elements in each layer of the medium and determining fluid flows (steady-state flows e.g.) through the discretized network while imposing boundary pressure conditions and fluid transmissivities to each couple of neighboring nodes. The method allows for a systematic linking of fractured reservoir characterization models with dual-porosity simulators in order to create a more realistic modeling of a fractured subsurface geological structure.

Abstract: Modelling method for optimizing faster and more realistically the displacement conditions, in a porous medium wettable by a first fluid (water for example), of a mixture of fluids including this wetting fluid and at least another fluid (oil and possibly gas).

Abstract: The present invention provides a method and apparatus for optimizing the treatment of a well. Initially, data from numerous sources is collected. Some of the data represents the location of objects found on a common map, e.g., rivers, towns, county lines, highways, etc. Another part of the data is data relating to a well. This data includes a wide variety of information that can be useful in determining how to treat a nearby well. This data is then integrated where it can be easily accessed by a user. Next, the user, using a geographic interface operating on a data processing system, selects a geographic region about which they are interested. The geographic interface assists the user in selecting the appropriate area. The user then uses the geographic interface to select some number of wells in the region of interest. This initial list of wells is refined by performing a SQL search of the initial list to select only the wells which have features or characteristics of interest to the user.

Abstract: This system and Method serve as both a raw data logger for well operation analysis and a well event logger for well performance analysis. An improved methodology of remote event and process variable logging and data retention designed specifically to address the needs of intermittently flowing gas wells is useful for eliminating gas slippage associated with intermittent or erratic gas flow conditions, eliminating measurement errors, and lowering operating costs. The well data can be scanned in seconds for its current flow situation, and as a set of specific conditions are met, a built-in control program reacts to those conditions by shutting down the well until certain pressure criteria are met to allow the well to flow again. To maintain measurement integrity, precise event logging of the valve positions to indicate the actual flowing period are included in the flow integration.

Abstract: A method for generating a flow profile of a wellbore whereby a first measurement and a second measurement are collected for each point of a sequence of selected points along the wellbore. For each respective point in the sequence of points, the arithmetic difference between the first and second measurements collected for the respective point is calculated, and the summation of the arithmetic differences for the respective point and for each point which follows the respective point in the sequence of points is recorded. A flow profile of the wellbore is generated by plotting the value of the summations calculated for each point of the sequence of points, wherein the magnitude of the potential productive flow from that point in the wellbore, is substantially proportional to the magnitude of the slope of the profile corresponding to that point.

Abstract: A computer implemented method for analyzing data utilizes a program and computer for processing input data in the form of a digitized map representing a physical structure. The microprocessor performs the steps and stores the results of the steps in an attached storage device. The computer is programed to employ or use various linear scales to establish critical dimensions of the curve and to analyze the dimensions in terms of orthogonal components. These are also stored for later processing or analysis to predict physical behavior associated with the structure. In a particular embodiment the curve represents a river bottom and predictions may be made about flows and the like.

Abstract: The method according to the invention permits adapting for any fluid, a known model representative of the circulation of a fluid in an annular space around a motionless pipe, centered or eccentric uniformly over the total length thereof, to more complex cases which are encountered in practice and notably in drilling. The invention comprises the application, to the pressure loss values obtained with the known model, of a first correction factor accounting for the eccentricity variations which the pipe may undergo notably because of the variations in the axial load applied or of straightness defects of the conduit, and of a second correction factor representative of the effects due to the rotation of the pipe. The method identifies the prominent pressure loss variations which are observed in narrow annular spaces. The method can be applied to narrow hole petroleum drilling (of the slim hole type).

Abstract: A method and apparatus for predicting distribution of reservoir permeability or porosity and pseudo relative permeability using well data and 3-D seismic data are disclosed, where a preferred first step in the method models the reservoir property of interest to provide model logs which are expressible as continuous curves of a reservoir property as a function of depth. The next step selects individual data points on the continuous curves traversing a reservoir layer and determines permeable trends for a multitude of column-like subvolumes which each enclose a portion of the selected data points. The subvolumes are then divided into a desired number of horizontal slices, with each slice containing a number of the model data points. An average value for the property in each slice is calculated, and the average values are plotted versus depth for each subvolume, thus providing a derived curve of depth versus the reservoir property.

Abstract: An automated gas permeameter measures permeabilities of porous samples, such as rocks, ranging from 0.1 milliDarcys to 10 Darcys within 0.5% under dry and humid conditions. The automated gas permeameter includes a program for estimating a coarse permeablity value. The program uses the coarse value to determine settling time for pressure to reach steady state within 0.1% and optimal operating conditions, such as the setting of mass flow rates imposed on the sample. Operating conditions of the permeameter are set by the program according to the resolution and range of flow controllers, accuracy of a pressure transducer, and the limit of applicability of Darcy's law for a sample.

Abstract: Methods of directly analyzing wireline well logging data to derive pore types, pore volumes and capillary pressure curves from the wireline logs are disclosed. A trained and validated neural network is applied to wireline log data on porosity, bulk density and shallow, medium and deep conductivity to derive synthetic pore type proportions as a function of depth. These synthetic data are then applied through a derived and validated capillary pressure curve data model to derive pore volume and pressure data as a function of borehole depth.