WO2011028197A1 - System and method of hydrocarbon formation modeling - Google Patents
System and method of hydrocarbon formation modeling Download PDFInfo
- Publication number
- WO2011028197A1 WO2011028197A1 PCT/US2009/055646 US2009055646W WO2011028197A1 WO 2011028197 A1 WO2011028197 A1 WO 2011028197A1 US 2009055646 W US2009055646 W US 2009055646W WO 2011028197 A1 WO2011028197 A1 WO 2011028197A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- processor
- approximation
- migration
- grid block
- buckley
- Prior art date
Links
- 238000000034 method Methods 0.000 title claims abstract description 63
- 229930195733 hydrocarbon Natural products 0.000 title claims abstract description 25
- 150000002430 hydrocarbons Chemical class 0.000 title claims abstract description 25
- 239000004215 Carbon black (E152) Substances 0.000 title claims abstract description 21
- 230000015572 biosynthetic process Effects 0.000 title claims abstract description 20
- 230000005012 migration Effects 0.000 claims abstract description 20
- 238000013508 migration Methods 0.000 claims abstract description 20
- 238000000605 extraction Methods 0.000 claims abstract description 13
- 238000006243 chemical reaction Methods 0.000 claims abstract description 10
- 230000000694 effects Effects 0.000 claims abstract description 10
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 25
- 230000035699 permeability Effects 0.000 claims description 16
- 230000004907 flux Effects 0.000 claims description 13
- 230000005484 gravity Effects 0.000 claims description 11
- 238000012937 correction Methods 0.000 claims description 8
- 230000008859 change Effects 0.000 claims description 5
- 238000004088 simulation Methods 0.000 claims description 4
- 238000002347 injection Methods 0.000 claims description 2
- 239000007924 injection Substances 0.000 claims description 2
- 230000000007 visual effect Effects 0.000 claims description 2
- 239000012530 fluid Substances 0.000 description 39
- 238000005755 formation reaction Methods 0.000 description 10
- 230000000704 physical effect Effects 0.000 description 4
- 239000000243 solution Substances 0.000 description 4
- VLKZOEOYAKHREP-UHFFFAOYSA-N n-Hexane Chemical compound CCCCCC VLKZOEOYAKHREP-UHFFFAOYSA-N 0.000 description 3
- 230000008901 benefit Effects 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 239000000203 mixture Substances 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 239000011148 porous material Substances 0.000 description 2
- 230000008569 process Effects 0.000 description 2
- 230000009471 action Effects 0.000 description 1
- 230000002411 adverse Effects 0.000 description 1
- 238000004458 analytical method Methods 0.000 description 1
- 238000010420 art technique Methods 0.000 description 1
- 239000001273 butane Substances 0.000 description 1
- 238000004364 calculation method Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 230000006870 function Effects 0.000 description 1
- 230000007774 longterm Effects 0.000 description 1
- IJDNQMDRQITEOD-UHFFFAOYSA-N n-butane Chemical compound CCCC IJDNQMDRQITEOD-UHFFFAOYSA-N 0.000 description 1
- OFBQJSOFQDEBGM-UHFFFAOYSA-N n-pentane Natural products CCCCC OFBQJSOFQDEBGM-UHFFFAOYSA-N 0.000 description 1
- 230000001151 other effect Effects 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 230000004044 response Effects 0.000 description 1
- 238000011144 upstream manufacturing Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F30/00—Computer-aided design [CAD]
- G06F30/20—Design optimisation, verification or simulation
- G06F30/23—Design optimisation, verification or simulation using finite element methods [FEM] or finite difference methods [FDM]
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V11/00—Prospecting or detecting by methods combining techniques covered by two or more of main groups G01V1/00 - G01V9/00
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V20/00—Geomodelling in general
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V2210/00—Details of seismic processing or analysis
- G01V2210/60—Analysis
- G01V2210/66—Subsurface modeling
- G01V2210/663—Modeling production-induced effects
Definitions
- Figure 1 shows a method in accordance with at least some embodiments.
- Figure 2 shows a computer system in accordance with at least some embodiments.
- 297943.01/2149-01100 “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to... .”
- the term “couple” or “couples” is intended to mean either an indirect or direct connection. Thus, if a first device couples to a second device, that connection may be through a direct connection or through an indirect connection via other devices and connections.
- finite difference technique models the reservoir as a plurality of grid blocks of particular size. Differential equations that predict the pressure of hydrocarbons and/or water within each grid block are solved. Based on the pressures calculated, fluid flow velocity at each face of each grid block is calculated.
- the finite difference technique is limited in the sense that the model cannot easily account for a flow of hydrocarbon and/or water that traverses more than one grid block within a modeled period ⁇ i.e., time step).
- time step for the finite difference technique may be limited to an extremely small size ⁇ e.g., a day or less).
- Another reservoir modeling technique that does not have the small time step limitation, is the streamline technique (also known as the Euler-Lagrangian technique).
- the streamline technique initially uses a finite difference-type technique to determine pressures and fluid flow ⁇ i.e., velocities) at the grid block boundaries (the Euler portion), but then uses the velocities to three-dimensionally interpolate fluid flow across many grid blocks (the Lagrangian portion). For example, the interpolated fluid flows may stream many grid blocks during the modeled period, hence the term "streamlines".
- the time step for the streamline technique can span significantly longer time periods ⁇ e.g., 60, 90, 180 days), and thus can more quickly model reservoir reaction to particular extraction techniques.
- the streamline technique does not readily account for: gravity; changes in relative permeability as water saturation changes; how capillary pressure affects fluid flow in the porous media; or fluid flow transverse to the streamline flow (transverse flux).
- the various embodiments are directed to systems and methods, along with computer-readable storage media storing instructions, that perform reservoir modeling with the benefits of both implicitly taking into account physical phenomenon such as relative permeability and capillary pressure, and also the ability to use large time steps.
- the description will first give an overview in words, followed by a more mathematical treatment.
- the various embodiments are directed to logically dividing the formation into a plurality of volumes, or grid blocks.
- the number of grid blocks may be on the order of millions of grid blocks, but greater or fewer such grid blocks may be equivalent ⁇ used.
- the grid blocks are of equal volume, but in other embodiments the grid blocks may be of varying volume based on the activity of movement of hydrocarbons and/or water within the grid block. For example, smaller grid blocks may be used in "active" areas, whereas larger grid blocks may be used in areas with little or no movement of fluids.
- the pressure of the fluids at each grid block boundary is calculated.
- the pressure is calculated using the finite differences technique ⁇ i.e., Eulerian technique). Based on the pressures at each grid block boundary, or more precisely differences in pressures considered across the grid block boundaries, flow velocities are determined.
- the progression of the fluid saturations is determined over the time step. Stated otherwise, the saturations (or masses) in each grid block at the end of the time step are determined. In particular embodiments, determining the progression of the saturations uses the
- the Lagrangian technique of this step of the process does not account for many physical properties of flow which effect accuracy of the calculated water saturation in each grid block.
- the water saturation calculated does not take into account: gravity; changes in relative permeability as water saturation changes; how capillary pressure affects fluid flow in the porous media; or fluid flow transverse to the streamline flow (transverse flux).
- performing the initial steps similar to the streamline technique represents a rough estimate or first approximation of the migration of the saturation ⁇ e.g., water saturation) in the modeled formation, and the first approximation is then modified or corrected to take into account some or all of the physical effects noted above.
- correcting for such physical effects should not adversely affect the length of the time step, as appears to be the case in the technique of the Osaka et al. paper noted above.
- the various embodiments calculate a value being the change in saturation within each grid block multiplied by the cell pore volume divided by the time step size. The value is an indication of the flow of fluid which has occurred during a time period.
- a total velocity of the fluids is determined.
- the method turns to solving simultaneous Buckley-Leverett equations modified to include at least one, but in particular embodiments a plurality, of considerations such as relative permeability as between the hydrocarbons and water in the grid block, capillary pressure, gravity, or transverse flux.
- Calculation of the fluid flow, fluid velocity and solving of the Buckley-Leverett may be performed multiple times until the value is reduced (and in some case minimized), but in some cases a single iteration is sufficient.
- the equations provide corrections to the water saturation determination. Unlike Osaka et al., the various embodiments do not result in numerical instability. Stated otherwise, the corrections do not impose time step limitations because the corrections can "move" the saturations across grid block boundaries.
- phase / ' is the total velocity, T, is the transmissibility times of the upstream mobility of phase / ' , ⁇ is the potential gradient at the interface of each grid block, and where the phase / ' is oil (o), water (w) and/or gas (g).
- Buckley-Leverett equations for each cell are solved using the total velocity number calculated from equation (2), with solutions iteratively determined until the error or residual values meet a predetermined value, such as a minimum.
- Equation (3) serves as an example but does not limit the technique to the solution of only water saturations. Other saturations and/or compositions could also be solved.
- the f w could take the following form:
- K m relative permeability of the water (given by the equation below)
- K ro relative permeability of the oil (given by the equation below)
- ⁇ 0 viscosity of the oil.
- the relative permeabilities are not constants in Equation (4).
- the equation regarding the relative permeability of water K m and relative permeabilit of oil " ra may take the form:
- the illustrative method displays a visual depiction of a location of the water saturation boundary (block 120), and the method ends (block 124).
- grid block sizes may be reduced in active areas to reduce computational times.
- the grid block sizes could be enlarged in those areas, and/or the system may refrain from solving the Buckley-Leverett equations in the areas identified as having little or no fluid movement.
- a mere two-component system could be assumed ⁇ i.e., oil and gas), and where significant fluid movement is expected, the model complexity could be increased to account for multiple components ⁇ e.g., methane, hexane, butane, etc.).
- FIG. 2 illustrates in greater detail a computer system 200, which is illustrative a computer system upon which the various embodiments may be practiced.
- the computer system 200 comprises a processor 202, and the processor couples to a main memory 204 by way of a bridge device 208.
- the processor 202 may couple to a long term storage device 210 ⁇ e.g., a hard drive, "floppy" disk, memory stick) by way of the bridge device 208.
- Programs executable by the processor 202 may be stored on the storage device 710, and accessed when needed by the processor 202.
- the program stored on the storage device 210 may comprise programs to implement the various embodiments of the present specification, including programs to
- 297943.01/2149-01100 implement modeling formation response to extraction techniques.
- the programs are copied from the storage device 210 to the main memory 204, and the programs are executed from the main memory 204.
- both the main memory 204 and storage device 210 are considered computer- readable storage mediums.
- the results of the modeling by the computer system 200 may be sent to a display device which may make a representation for viewing by a reservoir engineer or other person skilled in the art.
Landscapes
- Engineering & Computer Science (AREA)
- Life Sciences & Earth Sciences (AREA)
- Physics & Mathematics (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Fluid Mechanics (AREA)
- Environmental & Geological Engineering (AREA)
- Geochemistry & Mineralogy (AREA)
- General Physics & Mathematics (AREA)
- Theoretical Computer Science (AREA)
- Geophysics (AREA)
- Evolutionary Computation (AREA)
- Geometry (AREA)
- Computer Hardware Design (AREA)
- General Engineering & Computer Science (AREA)
- Management, Administration, Business Operations System, And Electronic Commerce (AREA)
Abstract
Description
Claims
Priority Applications (8)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
EP09849061.8A EP2457187B1 (en) | 2009-09-02 | 2009-09-02 | System and method of hydrocarbon formation modeling |
MX2012002684A MX2012002684A (en) | 2009-09-02 | 2009-09-02 | System and method of hydrocarbon formation modeling. |
CA2770602A CA2770602C (en) | 2009-09-02 | 2009-09-02 | System and method of hydrocarbon formation modeling |
CN200980161288.8A CN102576374B (en) | 2009-09-02 | 2009-09-02 | System and method of hydrocarbon formation modeling |
PCT/US2009/055646 WO2011028197A1 (en) | 2009-09-02 | 2009-09-02 | System and method of hydrocarbon formation modeling |
US13/391,927 US9390207B2 (en) | 2009-09-02 | 2009-09-02 | System and method of hydrocarbon formation modeling |
AU2009351922A AU2009351922B2 (en) | 2009-09-02 | 2009-09-02 | System and method of hydrocarbon formation modeling |
BR112012004477A BR112012004477A2 (en) | 2009-09-02 | 2009-09-02 | method, computer readable medium, and computer system |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
PCT/US2009/055646 WO2011028197A1 (en) | 2009-09-02 | 2009-09-02 | System and method of hydrocarbon formation modeling |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2011028197A1 true WO2011028197A1 (en) | 2011-03-10 |
Family
ID=43649538
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2009/055646 WO2011028197A1 (en) | 2009-09-02 | 2009-09-02 | System and method of hydrocarbon formation modeling |
Country Status (8)
Country | Link |
---|---|
US (1) | US9390207B2 (en) |
EP (1) | EP2457187B1 (en) |
CN (1) | CN102576374B (en) |
AU (1) | AU2009351922B2 (en) |
BR (1) | BR112012004477A2 (en) |
CA (1) | CA2770602C (en) |
MX (1) | MX2012002684A (en) |
WO (1) | WO2011028197A1 (en) |
Cited By (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN103246820A (en) * | 2013-05-21 | 2013-08-14 | 中国石油大学(北京) | Oil and gas reservoir numerical simulation calculation method |
CN104929624A (en) * | 2015-04-22 | 2015-09-23 | 中国地质大学(武汉) | Method for calculating secondary migration rate of crude oil driven by overpressure |
CN105160146A (en) * | 2015-07-07 | 2015-12-16 | 中国石油天然气股份有限公司 | Water flooding characteristic relation chart generation method and apparatus |
RU2738558C1 (en) * | 2020-06-10 | 2020-12-14 | Публичное акционерное общество «Татнефть» имени В.Д. Шашина | Method for development of low-permeability headers |
Families Citing this family (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2015065453A1 (en) * | 2013-10-31 | 2015-05-07 | Landmark Graphics Corporation | Determining pressure within a sealed annulus |
US10242136B2 (en) * | 2015-05-20 | 2019-03-26 | Saudi Arabian Oil Company | Parallel solution for fully-coupled fully-implicit wellbore modeling in reservoir simulation |
CA3030180A1 (en) * | 2016-10-14 | 2018-04-19 | Conocophillips Company | Connectivity based approach for field development optimization |
WO2020122892A1 (en) * | 2018-12-12 | 2020-06-18 | Halliburton Energy Services, Inc. | Borehole gravity analysis for reservoir management |
CN114320243B (en) * | 2022-03-11 | 2022-05-06 | 中国石油大学(华东) | Natural gas hydrate reservoir multi-branch horizontal well gravel packing simulation experiment system |
Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US7027354B2 (en) * | 2003-09-22 | 2006-04-11 | 4Th Wave Imaging Corp. | Method of obtaining pore pressure and fluid saturation changes in subterranean reservoirs by forward modeling |
US20080208539A1 (en) * | 2006-06-18 | 2008-08-28 | Chevron U.S.A. Inc. | Method, apparatus and system for reservoir simulation using a multi-scale finite volume method including black oil modeling |
Family Cites Families (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
BRPI0620170A2 (en) * | 2005-12-22 | 2011-11-01 | Chevron Usa Inc | method and system for predicting a property of at least one fluid in an underground reservoir, method for simulating heavy oil flow in an underground reservoir, and program storage device containing instructions for performing a reservoir simulation method |
-
2009
- 2009-09-02 WO PCT/US2009/055646 patent/WO2011028197A1/en active Application Filing
- 2009-09-02 BR BR112012004477A patent/BR112012004477A2/en not_active IP Right Cessation
- 2009-09-02 CN CN200980161288.8A patent/CN102576374B/en not_active Expired - Fee Related
- 2009-09-02 US US13/391,927 patent/US9390207B2/en active Active
- 2009-09-02 AU AU2009351922A patent/AU2009351922B2/en not_active Ceased
- 2009-09-02 CA CA2770602A patent/CA2770602C/en not_active Expired - Fee Related
- 2009-09-02 EP EP09849061.8A patent/EP2457187B1/en active Active
- 2009-09-02 MX MX2012002684A patent/MX2012002684A/en active IP Right Grant
Patent Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US7027354B2 (en) * | 2003-09-22 | 2006-04-11 | 4Th Wave Imaging Corp. | Method of obtaining pore pressure and fluid saturation changes in subterranean reservoirs by forward modeling |
US20080208539A1 (en) * | 2006-06-18 | 2008-08-28 | Chevron U.S.A. Inc. | Method, apparatus and system for reservoir simulation using a multi-scale finite volume method including black oil modeling |
Non-Patent Citations (4)
Title |
---|
BLUNT MARTIN J. ET AL.: "Prediction of Gas Injection Performance for Heterogeneous Reservoirs", ANNUAL TECHNICAL REPORT, December 1999 (1999-12-01), TULSA, OK(US), XP008152213 * |
G. ENCHERY ET AL.: "An improved pressure and saturation downscaling process for a better integration of 4D seismic data together with production history", SPE PAPERS 107088, 11 June 2007 (2007-06-11), pages 1 - 7 |
ICHIRO OSAKO: "TIMESTEP SELECTION DURING STREAMLINE SIMULATION VIA TRANSVERSE FLUX CORRECTION", A THESIS, December 2003 (2003-12-01), XP008152210 * |
See also references of EP2457187A4 |
Cited By (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN103246820A (en) * | 2013-05-21 | 2013-08-14 | 中国石油大学(北京) | Oil and gas reservoir numerical simulation calculation method |
CN104929624A (en) * | 2015-04-22 | 2015-09-23 | 中国地质大学(武汉) | Method for calculating secondary migration rate of crude oil driven by overpressure |
CN104929624B (en) * | 2015-04-22 | 2018-04-17 | 中国地质大学(武汉) | A kind of computational methods of the lower crude oil secondary migration speed of superpressure driving |
CN105160146A (en) * | 2015-07-07 | 2015-12-16 | 中国石油天然气股份有限公司 | Water flooding characteristic relation chart generation method and apparatus |
CN105160146B (en) * | 2015-07-07 | 2018-08-10 | 中国石油天然气股份有限公司 | Water-flooding characteristics relationship plate generation method and device |
RU2738558C1 (en) * | 2020-06-10 | 2020-12-14 | Публичное акционерное общество «Татнефть» имени В.Д. Шашина | Method for development of low-permeability headers |
Also Published As
Publication number | Publication date |
---|---|
CN102576374A (en) | 2012-07-11 |
US20120179439A1 (en) | 2012-07-12 |
EP2457187A4 (en) | 2015-10-07 |
MX2012002684A (en) | 2012-06-13 |
AU2009351922A1 (en) | 2012-03-01 |
CA2770602C (en) | 2017-02-14 |
EP2457187B1 (en) | 2020-06-03 |
BR112012004477A2 (en) | 2016-03-22 |
US9390207B2 (en) | 2016-07-12 |
CA2770602A1 (en) | 2011-03-10 |
EP2457187A1 (en) | 2012-05-30 |
AU2009351922B2 (en) | 2015-09-17 |
CN102576374B (en) | 2015-04-08 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
AU2009351922B2 (en) | System and method of hydrocarbon formation modeling | |
AU2015210609B2 (en) | Geomechanical and geophysical computational model for oil and gas stimulation and production | |
Jaffré et al. | A discrete fracture model for two-phase flow with matrix-fracture interaction | |
US20150338550A1 (en) | Method and system for characterising subsurface reservoirs | |
Moncorgé et al. | Modified sequential fully implicit scheme for compositional flow simulation | |
US20190310392A1 (en) | Global surface paleo-temperature modeling tool | |
Lautenschläger et al. | Advances on partial coupling in reservoir simulation: A new scheme of hydromechanical coupling | |
Ding | Modeling of matrix/fracture transfer with nonuniform-block distributions in low-permeability fractured reservoirs | |
Rankin et al. | A high order method for solving the black-oil problem in porous media | |
Tanaka et al. | A novel approach for incorporation of capillarity and gravity into streamline simulation using orthogonal projection | |
Terada | Rapid Coupled Flow and Geomechanics Simulation using the Fast Marching Method | |
Yang et al. | Multiphase upscaling using approximation techniques | |
US20210182460A1 (en) | Semi-Elimination Methodology for Simulating High Flow Features in a Reservoir | |
Nevmerzhitskiy | Development of models for filtration simulation in nonlinear media | |
Kippe et al. | A method to improve the mass balance in streamline methods | |
Klemetsdal et al. | Implicit high-resolution compositional simulation with optimal ordering of unknowns and adaptive spatial refinement | |
Szyndel et al. | Implementing A Hardware Agnostic Commercial Black-oil Reservoir Simulator | |
Niu et al. | Insights into field application of EOR techniques from modeling of tight reservoirs with complex high-density fracture network | |
Lei et al. | A discrete fracture model coupled with geomechanics for low-permeability waterflooding reservoirs | |
Khait et al. | Operator-based linearization for modeling of low-enthalpy geothermal processes | |
Kasiri Bidhendi et al. | Enhancing acid fracture design in carbonate formation using a dynamic up-scaling procedure to convert discrete fracture network to dual continuum | |
Annewandter et al. | High-resolution numerical simulations of capillary trapping for carbon dioxide in fractured formations | |
Moyner | Dynamic Saturation Reconstruction for Multiphase Flow by Time-Of-Flight Fill Functions | |
Nevmerzhitskiy | Applying Streamline Method for Viscoplastic Oil Flow Simulation | |
Aronson et al. | Pressure-stabilized fixed-stress iterative solutions of compositional poromechanics |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
WWE | Wipo information: entry into national phase |
Ref document number: 200980161288.8 Country of ref document: CN |
|
121 | Ep: the epo has been informed by wipo that ep was designated in this application |
Ref document number: 09849061 Country of ref document: EP Kind code of ref document: A1 |
|
WWE | Wipo information: entry into national phase |
Ref document number: 2009351922 Country of ref document: AU |
|
WWE | Wipo information: entry into national phase |
Ref document number: 2770602 Country of ref document: CA |
|
WWE | Wipo information: entry into national phase |
Ref document number: 2009849061 Country of ref document: EP |
|
WWE | Wipo information: entry into national phase |
Ref document number: 13391927 Country of ref document: US |
|
ENP | Entry into the national phase |
Ref document number: 2009351922 Country of ref document: AU Date of ref document: 20090902 Kind code of ref document: A |
|
NENP | Non-entry into the national phase |
Ref country code: DE |
|
WWE | Wipo information: entry into national phase |
Ref document number: MX/A/2012/002684 Country of ref document: MX |
|
REG | Reference to national code |
Ref country code: BR Ref legal event code: B01A Ref document number: 112012004477 Country of ref document: BR |
|
ENP | Entry into the national phase |
Ref document number: 112012004477 Country of ref document: BR Kind code of ref document: A2 Effective date: 20120228 |