11241results about "Permeability/surface area analysis" patented technology

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. A reservoir simulator will receive the structured grid and generate a set of simulation results which are displayed on a 3D Viewer for observation by a workstation operator.

A method of managing a fluid or gas reservoir is disclosed which assimilates diverse data having different acquisition time scales and spatial scales of coverage for iteratively producing a reservoir development plan that is used for optimizing an overall performance of a reservoir. The method includes: (a) generating an initial reservoir characterization, (b) from the initial reservoir characterization, generating an initial reservoir development plan, (c) when the reservoir development plan is generated, incrementally advancing and generating a capital spending program, (d) when the capital spending program is generated, monitoring a performance of the reservoir by acquiring high rate monitor data from a first set of data measurements taken in the reservoir and using the high rate monitor data to perform well-regional and field-reservoir evaluations, (e) further monitoring the performance of the reservoir by acquiring low rate monitor data from a second set of data measurements taken in the reservoir, (f) assimilating together the high rate monitor data and the low rate monitor data, (g) from the high rate monitor data and the low rate monitor data, determining when it is necessary to update the initial reservoir development plan to produce a newly updated reservoir development plan, (h) when necessary, updating the initial reservoir development plan to produce the newly updated reservoir development plan, and (i) when the newly updated reservoir development plan is produced, repeating steps (c) through (h). A detailed disclosure is provided herein relating to the step (a) for generating the initial reservoir characterization and the step (b) for generating the initial reservoir development plan.

Methods, systems, and products for monitoring an air filter. Methods involve determining a difference between a baseline pressure differential and a current pressure differential, the differential pressure between pressure at an upstream side of the filter and pressure at a downstream side of the filter. The baseline pressure differential may be set automatically or by a user. Reaching or exceeding a predetermined threshold triggers an indication of a clogged condition. The method also includes monitoring the air filter condition intermittently. The filter monitor may operate for extended periods in a sleep state and intermittently power up to a wake state to measure the current pressure differential and compare the current pressure differential with a baseline pressure differential.

Improved integrity test, priming sequence and bag height detection tests, apparatuses and methods for a medical fluid delivery system are provided. The integrity test includes a plurality of air pressure decay tests, using positive and negative pressure. The priming sequence includes pumping fluid through a portion of a patient line to be primed to overcome air in the line and other potential obstacles. The head height test measures a pressure build-up or drop-off within a pump chamber of a membrane pump. The measured pressure corresponds to a head height between a fluid supply and the pump or between the pump and a fluid drain. A determination is made whether the corresponding head height is acceptable.

PCT No. PCT/AU96/00144 Sec. 371 Date Jan. 12, 1998 Sec. 102(e) Date Jan. 12, 1998 PCT Filed Mar. 15, 1996 PCT Pub. No. WO96/28236 PCT Pub. Date Sep. 19, 1996A method and apparatus for determining the fouling effect of a feedstream on a filter having known characteristics disclosed. The method comprises passing the feedstream through a filter (5) having known characteristics; determining the change in resistance to flow of the feedstream across the filter, either continuously or over a number of time intervals and from this data, calculating a feed fouling index (FFI) representative of the fouling characteristics of the feedstream with respect to the filter. A method and apparatus for monitoring the operation of a filtration system is also disclosed the method comprising sampling system parameter values at selected locations within the filtration system at a predetermined sampling rate; generating a parameter profile characteristic from the sampled parameter values at predetermined intervals of time; and analysing the parameter profile characteristic to determine correct operation of the filtration system. A further method and apparatus of monitoring and controlling a filtering system based on backwash efficiency is also disclosed, the method comprising determining resistance values of filtering elements used in the filtering system at predetermined times during the backwash cycle of the system by monitoring a number of operating parameters of the system; calculating a backwash efficiency value representative of the efficiency of the backwash cycle of the filtering system using the resistance values determined; and controlling the operation of the filtering system in dependence on the value of the backwash efficiency calculated.

A process to determine optimal completion type and design prior to drilling of a hydrocarbon producing well utilizing information from hydrocarbon recovery modeling such as reservoir, geo-mechanical, and material modeling over the production life of the well. An embodiment of the process includes obtaining information regarding pore pressure depletion, stress magnitudes and orientations, and strength of rock formation from hydrocarbon recovery modeling to determine optimum well completion design including the selection of a completion type, trajectory, and location. Additionally, the process may also consider probable failure mechanisms and identified completion requirements, and their corresponding effect on completion options.

The invention relates to an object-oriented method for simulating a property of at least one fluid in a fluid-containing physical system in which the physical system is represented by a multiplicity of volumetric cells and a multiplicity of connections between cells. The method uses cell-group objects and connection-group objects in the simulation. The invention can optionally comprise additional objects such as an object containing the entire model of the simulation and another object containing a portion of the entire model.

A method of determining the amount of particulate accumulated in a particulate filter, is based on determining possible variations in the spatial distribution and/or physical-chemical properties of the particulate as a function of engine operating conditions and past particulate accumulation in the particulate filter. A number of reference values defining a relationship between the amount of particulate accumulated in the particulate filter and the pressure drop across the particulate filter are mapped, each of the reference values relating to a respective steady engine operating condition in which particulate is accumulated in the particulate filter. In a given engine operating condition, an operating value of the parameter is then determined as a function of the reference value of the parameter relative to the same steady engine operating condition, and of past particulate accumulation in the particulate filter.

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.

A method for forecasting performance for and characterizing the properties of a multilayer low permeability gas reservoir. The method includes a coupled well/reservoir predictive model that accounts for pressure drop between layers, allowing accurate, rigorous, and rapid forecasting of reservoir performance. The method provides estimates of individual layer properties such as in-situ permeability, skin factor, fracture half-length, fracture conductivity, drainage area, etc. by simultaneously history matching production data and production log data using the coupled well/reservoir predictive model.

A method of real time field wide reservoir management comprising the steps of processing collected field wide reservoir data in accordance with one or more predetermined algorithms to obtain a resultant desired field wide production/injection forecast, generating a signal to one or more individual well control devices instructing the device to increase or decrease flow through the well control device, transmitting the signal to the individual well control device, opening or closing the well control device in response to the signal to increase or decrease the production for one or more selected wells on a real time basis. The system for field wide reservoir management comprising a CPU for processing collected field wide reservoir data, generating a resultant desired field wide production/injection forecast and calculating a target production rate for one or more wells and one or more down hole production/injection control devices.

A “near wellbore modeling” software will, when executed by a processor of a computer, model a localized area of a reservoir field which surrounds and is located near a specific wellbore in the reservoir field by performing the following functions: (1) receive input data representative of a reservoir field containing a plurality of wellbores, (2) establish a boundary around one specific wellbore in the reservoir field which will be individually modeled and simulated, (3) impose an “fine scale” unstructured grid inside the boundary consisting of a plurality of tetrahedrally shaped grid cells and further impose a fine scale structured grid about the perforated sections of the specific wellbore, (4) determine a plurality of fluxes/pressure values at the boundary, the fluxes/pressure values representing characteristics of the reservoir field located outside the boundary, (5) establish one or more properties for each tetrahedral cell of the unstructured grid and each cylindrical grid cell of the structured grid, (6) run a simulation, using the fluxes/pressure values at the boundary to mimic the reservoir field outside the boundary and using the fine scale grid inside the boundary, to thereby determine a plurality of simulation results corresponding, respectively, to the plurality of grid cells located inside the boundary, the plurality of simulation results being representative of a set of characteristics of the reservoir field located inside the boundary, (7) display the plurality of simulation results which characterize the reservoir field located inside the boundary, and (8) reintegrate by coarsening the grid inside the boundary, imposing a structured grid outside the boundary, and re-running a simulation of the entire reservoir field.

The invention is a method for automated management of hydrocarbon gathering systems. Measurement data is automatically collected from automated measurement and control devices that are located in a hydrocarbon production system The data that is collected is compared with data stored in a database. The comparison of data is used to automatically schedule tests of the plurality of automated measurement and control devices. The invention also automatically collects well test data, system balance data, and hydrocarbon composition data and uses the collected data to manage the hydrocarbon production and delivery process. The invention also automatically generates periodic grid reports concerning the status of the gathering system.

The invention discloses a coal-rock hydraulic fracturing testing method under a true triaxial state. The coal-rock hydraulic fracturing testing method under the true triaxial state comprises the following steps: 1) preparing a test piece; 2) installing the test piece; 3) pre-loading; 4) loading; 5) hydraulically fracturing; 6) unloading; 7) storing all data recorded by a data collection system, taking out the test piece and observing the shape of the test piece. According to the coal-rock hydraulic fracturing testing method, the real work condition can be more really simulated, and a theoretical basis is provided for solving on-site problems.

The invention stimulates the production of an oil reservoir by carrying out a sequence of steps of constructing a flow simulator from physical data measured in the oil reservoir; determining a first analytical model relating the production of the reservoir as a function of time by taking account of parameters having an influence on the production of the reservoir, the first model best adjusting to a finite number of production values obtained by the reservoir simulator; selecting at least one new production value, this new value being obtained by the reservoir simulator; and determining a second model by adjusting the first model so that the second model interpolates the new production value.

The invention discloses a true triaxial loading and unloading test device for large-size bedded pressure-bearing rock and a testing method. The device comprises a confining pressure loading module, a sample storage and water outlet module, a confined water loading module, a load loading module and a signal collecting and processing system, wherein the confining pressure loading module comprises two horizontal loading and unloading systems which are independent and perpendicular to each other and is used for performing horizontal load loading and unloading on the wrapped sample storage and water outlet module; the confined water loading module is located at the bottom of the sample storage and water outlet module and is used for performing confined water loading and unloading on the bottom of the bedded rock; the load loading module is located at the top of the sample storage and water outlet module and is used for performing vertical load loading and unloading on the top of the bedded rock; the signal collecting and processing system is used for collecting and analyzing signals in a test process. The test device realizes the true triaxial test of the bedded rock through four independent loading and unloading systems, truly simulates three-way anisobaric stress state of the coal-series bedded pressure-bearing rock and is more true and more reliable than a conventional triaxial test.

The invention discloses a fluid-solid-heat coupling triaxial servo percolation device for gas-contained coal, comprising a lifting stand, a hydraulic servo control system, an axial loading device mounted at the top of the lifting stand and a triaxial pressure chamber connected with the lower end of the axial loading device. A thermostatic water tank is arranged below the triaxial pressure chamber; a movable worktable is arranged above the thermostatic water tank; the lower end of the triaxial pressure chamber is arranged on the movable worktable; heating tubes are arranged in the thermostatic water tank; and a water inlet valve, a water drain valve and a water-bath circulating water pump are arranged outside the thermostatic water tank and are communicated with the thermostatic water tank. In the hydraulic servo control system, an axial compression loading oil pump is communicated with an oil inlet and an oil outlet by a pipeline, and a peripheral compression loading oil pump is communicated with an oil intake/drain hole by a pipeline. The fluid-solid-heat coupling triaxial servo percolation device for gas-contained coal can carry out the research of gas-contained coal percolation tests in states, such as different terrestrial stresses, different gas pressures, different temperatures, and the like and the distortion and failure characteristics of the gas-contained coal in a percolation process.

The invention relates to a method of performing an oilfield operation of an oilfield having at least one wellsite, each wellsite having a wellbore penetrating a subterranean formation for extracting fluid from an underground reservoir therein. The method steps include obtaining a plurality of real-time parameters from a plurality of sensors disposed about the oilfield, wherein the plurality of real-time parameters comprise at least one selected from a group consisting of real-time flow rate data and real-time pressure data of the wellbore, configuring a gridless analytical simulator for simulating the underground reservoir based on the plurality of real-time parameters, generating real-time simulation results of the underground reservoir and the at least one wellsite in real-time using the gridless analytical simulator, and performing the oilfield operation based on the real-time simulation results

Automated monitoring and management of well tests of hydrocarbon wells in a production field. Routing of the output of a well to a flow meter, separated from the output from other wells in the field, is detected by a computer system such as a server. Measurement data including the flow as measured by the flow meter, and also other measurements such as temperatures and pressures contemporaneous with the flow meter measurements, are acquired by the computer system; a stable period is identified, over which the flow test measurement data are considered valid. Upon completion of a specified duration or upon a change in the flow environment, the computer system notifies the user of the completion of the flow test. The flow test results can be used to modify predictive well models, with the modification dependent on validation by the user. The system can also plan and schedule future flow tests.

A fully-parallelized, highly-efficient compositional implicit hydrocarbon reservoir simulator is provided. The simulator is capable of solving giant reservoir models, of the type frequently encountered in the Middle East and elsewhere in the world, with fast turnaround time. The simulator may be implemented in a variety of computer platforms ranging from shared-memory and distributed-memory supercomputers to commercial and self-made clusters of personal computers. The performance capabilities enable analysis of reservoir models in full detail, using both fine geological characterization and detailed individual definition of the hydrocarbon components present in the reservoir fluids.

A system and method monitor a hydrocarbon reservoir for drainage in volumetric three dimensions. Monitoring between wells is imperative for optimum reservoir management and is achieved by mapping the hydrocarbon fluid pathways in a producing reservoir. Unlike conventional 4D or time-lapse reflection seismic imaging systems that use a controlled active seismic source and records reflected seismic energy at receivers, the system and method exploit the minute vibrations, or micro-earthquakes generated in the reservoir layers that are induced by fluid movement. These microseisms are detected as the fluids move in the reservoir.

A method, system, and computer program product for performing oilfield surveillance operations. The oilfield has a subterranean formation with geological structures and reservoirs therein. The oilfield is divided into a plurality of patterns, with each pattern comprising a plurality of wells. Historical production/injection data is obtained for the plurality of wells. Two independent statistical treatments are performed to achieve a common objective of production optimization. In the first process, wells and/or patterns are characterized based on Heterogeneity Index results and personalities with the ultimate goal of field production optimization. In the second process, the history of the flood is divided into even time increments. At least two domains for each of the plurality of wells are determined. Each of the at least two domains are centered around each of the plurality wells. A first domain of the at least two domains has a first orientation. A second domain of the at least two domains has a second orientation. An Oil Processing Ratio is determined for each of the at least two domains, then an Oil Processing Ratio Strength Indicator is calculated. At least one Meta Pattern within the field is then identified. An oilfield operation can then be guided based either on the well and/or pattern personality or the at least one Meta Pattern.