CN106021778A - Method for determining CO2 simulation displacement performance miscibility pressure - Google Patents
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- 238000000034 method Methods 0.000 title claims abstract description 33
- 238000006073 displacement reaction Methods 0.000 title claims abstract description 19
- 238000004088 simulation Methods 0.000 title claims abstract description 19
- 239000012530 fluid Substances 0.000 claims abstract description 35
- 230000008859 change Effects 0.000 claims abstract description 5
- 230000000704 physical effect Effects 0.000 claims abstract description 4
- 230000015572 biosynthetic process Effects 0.000 claims description 12
- 238000002474 experimental method Methods 0.000 claims description 12
- 230000003993 interaction Effects 0.000 claims description 4
- 238000012360 testing method Methods 0.000 claims description 4
- 238000011161 development Methods 0.000 abstract description 6
- 238000011160 research Methods 0.000 abstract description 3
- 230000007246 mechanism Effects 0.000 abstract description 2
- 238000012544 monitoring process Methods 0.000 abstract 1
- 238000005325 percolation Methods 0.000 abstract 1
- 239000003921 oil Substances 0.000 description 47
- 239000007789 gas Substances 0.000 description 11
- 239000010779 crude oil Substances 0.000 description 5
- RTZKZFJDLAIYFH-UHFFFAOYSA-N Diethyl ether Chemical compound CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 description 4
- 238000005516 engineering process Methods 0.000 description 4
- YXFVVABEGXRONW-UHFFFAOYSA-N Toluene Chemical compound CC1=CC=CC=C1 YXFVVABEGXRONW-UHFFFAOYSA-N 0.000 description 3
- 230000000694 effects Effects 0.000 description 3
- 239000000523 sample Substances 0.000 description 3
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 2
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 2
- 239000003208 petroleum Substances 0.000 description 2
- 230000008569 process Effects 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 description 1
- 238000009825 accumulation Methods 0.000 description 1
- 230000008901 benefit Effects 0.000 description 1
- BVKZGUZCCUSVTD-UHFFFAOYSA-N carbonic acid Chemical compound OC(O)=O BVKZGUZCCUSVTD-UHFFFAOYSA-N 0.000 description 1
- 239000003153 chemical reaction reagent Substances 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 230000007423 decrease Effects 0.000 description 1
- 238000009795 derivation Methods 0.000 description 1
- 239000000284 extract Substances 0.000 description 1
- 239000003546 flue gas Substances 0.000 description 1
- 239000008398 formation water Substances 0.000 description 1
- 230000008676 import Effects 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
- 238000011002 quantification Methods 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 238000012956 testing procedure Methods 0.000 description 1
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- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F30/00—Computer-aided design [CAD]
- G06F30/30—Circuit design
- G06F30/36—Circuit design at the analogue level
- G06F30/367—Design verification, e.g. using simulation, simulation program with integrated circuit emphasis [SPICE], direct methods or relaxation methods
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- 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
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/164—Injecting CO2 or carbonated water
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- Chemical Kinetics & Catalysis (AREA)
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- Evolutionary Computation (AREA)
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Abstract
The invention discloses a method for determining CO2 simulation displacement performance miscibility pressure. The method comprises the steps of 1, measuring interfacial tension between CO2 and in-place oil; 2, inputting the physical property parameter of in-place oil into a PVTi module of Eclipse numerical simulation software, conducting fluid parameter fitting to enable fluid in the PVTi module to have the same property as in-place oil, simulating CO2 displacement in the PVTi module, monitoring the tension of an oil gas interface in the PVTi module when pressure is the minimum miscibility pressure in the initial stage of a measured oil deposit, and exporting fluid property data when the tension of the oil gas interface is zero; 3, substituting the exported fluid property data into a numerical simulation model of a target oil field for virtual development, and determining the miscibility pressure at the moment by analyzing the interfacial tension change of each grid in the numerical simulation model. The method is a perfect method for quantitative representation of dynamic miscibility pressure by means of physical and numerical simulation ways, and a key technical means is provided for research of CO2 displacement percolation mechanism and development law.
Description
Technical field
The present invention relates to a kind of simulation CO2The determination method of the dynamic miscible pressure of displacement, belongs to CO2The miscible displacement of reservoir is hidden and is opened
The field of sending out.
Background technology
CO2It is a kind of gas that dissolubility is the highest in You Heshui, when it is dissolved in crude oil in a large number, not only may be used
So that crude oil volumetric expansion, viscosity decline, also can reduce the interfacial tension between profit, thus improve blowhole Central Plains
Oil oil displacement efficiency, and reach CO when pressure under reservoir temperature2When driving minimum miscibility pressure, CO2To reach with crude oil
Mixed phase state, oil displacement efficiency can rise to 100%；CO2The carbonic acid formed after being dissolved in water may also operate as acidization.
It is not affected by conditions such as well depth, temperature, pressure, formation water salinitys, due to any of the above effect and widely
Use condition, notes CO2The application improving recovery ratio is quite varied.
But carrying out CO2Drive in development process, along with CO2Continuous injection, it constantly extracts in formation fluid
Light components so that underground fluid component gradually becomes weight, and miscible pressure will constantly increase the most in theory, but use
The minimum miscibility pressure that laboratory physical simulation experiment obtains is only the minimum miscibility pressure at oil reservoir development initial stage, along with oil
If the exploitation in field also uses initial minimum miscibility pressure, mixed phase development effectiveness to be greatly reduced.Due to formation fluid
Being continually changing of component, some parameters needed in empirical formula method also cannot obtain at any time, therefore standard empirical formula
Method also cannot obtain dynamic miscible pressure in oil reservoir.Therefore a kind of CO of offer is provided badly2The dynamic miscible pressure of displacement is really
Determine method.
Summary of the invention
It is an object of the invention to provide a kind of simulation CO2The determination method of the dynamic miscible pressure of displacement, the present invention is CO2
The research of displacement of reservoir oil seepage flow mechanism and exploitation rule provides key technology means.
Present invention determine that the principle of method is as follows:
Sessile drop method is used to measure formation fluid and CO2Gas shape under formation temperature, different pressures, according to oil droplet
Shape Andreas select face method to calculate CO2Interfacial tension between-in-place oil, repeat the above steps carries out other
CO under pressure2-in-place oil interfacial tension is tested, until layer formation oil is at CO2In can not form complete oil droplet
Time terminate experiment.Carry out the PVTi matching of fluid, by adjust the OmegaA of fluid, OmegaB, critical temperature,
The parameters such as critical pressure, binary interaction coefficient, matching fluid bubble point pressure, relative volume coefficient, viscosity, density,
CO2Swell and minimum miscibility pressure experiment, be allowed to match with experimental result.By the physical properties of fluids after matching
Parameter imports in realistic model, the interfacial tension value being calculated under different time by model.Inverting different time oil
Hide the strata pressure that median surface tension force has been just 0 region, be CO in oil reservoir2Drive state miscible pressure.
Simulation CO provided by the present invention2The determination method of the dynamic miscible pressure of displacement, comprises the steps:
(1)CO2The mensuration of the interfacial tension between-in-place oil
At the formation temperature with under different pressures, sessile drop method is used to measure CO2And the interfacial tension between in-place oil,
To CO2And the relation curve between interfacial tension and pressure between in-place oil；According to described relation curve, when described
The pressure corresponding when being zero of interfacial tension is the minimum miscibility pressure under oil reservoir initial situation；
(2) fluid PVTi matching
1) physical parameter of in-place oil is inputted to the PVTi module of Eclipse numerical simulation software, fitted flow
The bubble point pressure of body, relative volume coefficient, viscosity, density, CO2Swell and minimum miscibility pressure experiment,
Make the described fluid in described PVTi module identical with the character of described in-place oil；
2) in described PVTi module, CO is simulated2Displacement, when pressure is that the described oil reservoir that step (1) measures is initial
In the case of minimum miscibility pressure time, monitor the interface of oil and gas tension force in described PVTi module；When the described interface of oil and gas
When tension force is zero, now derive fluid properties data；
(3) numerical simulation
The described fluid properties data derived are put in the numerical simulator of subject oil field, carry out virtual development；Logical
Cross the interfacial tension change analyzing each grid in described numerical simulator, i.e. can determine that miscible pressure now.
In above-mentioned determination method, step (2) 1) in, described physical parameter is the component of described in-place oil, height
The interfacial tension experimental result that pressure physical property and/or step (1) measure.
Described high pressure property refer in oil reservoir oil, gas and water physicochemical properties with the Changing Pattern of pressure.
In above-mentioned determination method, step (2) 1) in, by adjust OmegaA in described PVTi module,
OmegaB, critical temperature, critical pressure, binary interaction coefficient realize the matching to described fluid.
In above-mentioned determination method, in step (3), described virtual development refers to the actual number in application target oil field
Value analogue model, uses the exploitation system of subject oil field, obtains opening under different development phases by numerical simulation software
Send out effect.
The inventive method has the advantage that
(1) the invention provides a kind of technical method, cannot consider with exploitation in Typical physical simulation, empirical equation
Carry out fluid properties change cause miscible pressure change on the premise of, utilize physical modeling's means and numerical simulation to combine
Method so that dynamically miscible pressure is determined.
(2) The present invention gives quantification, exercisable technical method and implement step.
(3) present invention is applicable not only to CO2Oil reservoirs developmental research field, it is also possible to for oozing of other gas-drive pools
Stream law study uses and reference, such as N2Drive, flue gas flooding etc..
Accompanying drawing explanation
Fig. 1 is in-place oil-CO2Interface tension force experiment flow.
Fig. 2 is interface of oil and gas tension variation field figure in model.
Fig. 3 is numerical simulation dynamic miscible pressure figure.
Detailed description of the invention
Experimental technique used in following embodiment if no special instructions, is conventional method.
Material used in following embodiment, reagent etc., if no special instructions, the most commercially obtain.
The present invention mainly utilizes indoor physical simulation technology and numerical simulation technology to realize the quantitative table to dynamic miscible pressure
Levy.
(1) in-place oil-CO2Interface tension force experiment flow
Use stratum actual crude oil (the black 59 pieces of CO in Jilin2Oil reservoirs), application sessile drop method measures formation fluid and CO2
Gas interfacial tension under formation temperature, different pressures, experiment flow is as shown in Figure 1.
Testing procedure is as follows:
(1) with toluene and petroleum ether, the hanging drop room of High Temperature High Pressure hanging drop interfacial tensimeter is cleaned up, blow with hot nitrogen
Sweep to remove the petroleum ether of remaining, then to hanging drop room evacuation；
(2) test system is heated to experimental temperature formation temperature (formation temperature of each target block) constant temperature afterwards, to
CO is injected in hanging drop room2Gas pressurization reach required test pressure.
(3) after system temperature to be tested, pressure stability, by single-phase in-place oil sample under predetermined test pressure,
Hanging drop room is injected lentamente by capillary probe.
(4) when oil droplet will come off from tips of probes, the picture of oil droplet shape is taken by camera system, according to oil droplet
Shape Andreas select face method to calculate CO2Interfacial tension between-in-place oil.
(5), after again being cleaned up hanging drop room, repeat the above steps carries out the CO under other pressure2-in-place oil
Interfacial tension is tested, until layer formation oil is at CO2In terminate experiment when can not form complete oil droplet.
(6) as in-place oil and CO2When interfacial tension is zero, now the pressure in instrument is oil reservoir initial situation
Under minimum miscibility pressure.
(2) fluid PVTi fit procedure
(1) the PVTi module of Eclipse numerical simulation software is used to carry out the pvti matching of fluid.
(2) the interfacial tension experimental result of in-place oil component, high pressure property and said determination is inputted PVTi module
In, by parameters such as the OmegaA in adjustment model, OmegaB, critical temperature, critical pressures, matching fluid steeps
Point pressure, relative volume coefficient, viscosity, density, CO2Swell and minimum miscibility pressure experiment so that mould
In type, fluid properties is identical with underground fluid character.
(3) CO is simulated in a model2Displacement, the minimum miscibility pressure recorded in pressure is experimental procedure ()
Time, whether the interface of oil and gas tension force in model is zero, if be not zero, by adjusting binary interaction coefficient so that
The interfacial tension of the minimum miscibility pressure drag that experiment records is just zero, and derives fluid properties data now.
Interface of oil and gas tension variation field figure in model is as in figure 2 it is shown, CO as can be seen from Figure 22Drive leading edge (CO2Just
When contacting with crude oil), interfacial tension is bigger；Along with the carrying out of displacement, the place that the distance interface of oil and gas is the most remote, interface is opened
Power is the least, when by adjusting fluid parameter, under the conditions of the miscible pressure that step (1) records, interfacial tension is just
When zero, illustrate that now fluid PVTi matching terminates.
(3) numerical simulation
The fluid properties data of derivation are put into the black 59 pieces of CO in Jilin2In the actual numerical value analogue model of oil reservoirs, enter
Row virtual development, along with exploitation carrying out, in underground fluid, light components is extracted, heavy component gradually by residual and
Accumulation, changes by analyzing the interfacial tension of each grid in model, can effectively determine miscible pressure now.
As it is shown on figure 3, the force value that grid median surface tension force is corresponding when being 0, it is the mixed phase of now underground fluid
Pressure, the dynamic miscible pressure that should can be accurately obtained in this way in development process, effectively determining dynamic mixed phase
On the premise of pressure, CO can be effectively improved directly by adjusting exploitation system2The mixed phase effect driven.
Utilize the CO that the inventive method is predicted2Displacement dynamic miscible pressure error is less than 10%.
Claims (3)
1. a simulation CO2The determination method of the dynamic miscible pressure of displacement, comprises the steps:
(1)CO2The mensuration of the interfacial tension between-in-place oil
At the formation temperature with under different pressures, sessile drop method is used to measure CO2And the interfacial tension between in-place oil,
To CO2And the relation curve between interfacial tension and pressure between in-place oil；According to described relation curve, when described
The pressure corresponding when being zero of interfacial tension is the minimum miscibility pressure under oil reservoir initial situation；
(2) fluid PVTi matching
1) physical parameter of in-place oil is inputted to the PVTi module of Eclipse numerical simulation software, fitted flow
The bubble point pressure of body, relative volume coefficient, viscosity, density, CO2Swell and minimum miscibility pressure experiment,
Make the described fluid in described PVTi module identical with the character of described in-place oil；
2) in described PVTi module, CO is simulated2Displacement, when pressure is that the described oil reservoir that step (1) measures is initial
In the case of minimum miscibility pressure time, monitor the interface of oil and gas tension force in described PVTi module；When the described interface of oil and gas
When tension force is zero, now derive fluid properties data；
(3) numerical simulation
The described fluid properties data derived are put in the numerical simulator of subject oil field, carry out virtual development；Logical
Cross the interfacial tension change analyzing each grid in described numerical simulator, i.e. can determine that miscible pressure now.
The most according to claim 1 determine method, it is characterised in that: step (2) 1) in, described physical property
Parameter is the interfacial tension test result that the component of described in-place oil, high pressure property and/or step (1) measure.
The most according to claim 1 and 2 determine method, it is characterised in that: step (2) 1) in, pass through
Adjust the OmegaA in described PVTi module, OmegaB, critical temperature, critical pressure and binary interaction coefficient real
The now matching to described fluid.
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Cited By (16)
| Publication number | Priority date | Publication date | Assignee | Title |
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| CN106437640A (en) * | 2016-10-19 | 2017-02-22 | 中国石油化工股份有限公司 | Low-permeability reservoir CO2 and N2 mixed oil displacement method |
| CN106872594A (en) * | 2017-02-16 | 2017-06-20 | 中国石油大学(华东) | CO in one kind test saturated oils porous media2The method of concentration distribution and diffusion coefficient |
| CN106884635A (en) * | 2017-03-03 | 2017-06-23 | 中国石油大学(北京) | Low, the extra-low permeability oil reservoirs CO of one kind2Drive the assay method of minimum miscibility pressure |
| CN107066672A (en) * | 2017-01-17 | 2017-08-18 | 中海石油(中国)有限公司 | A kind of method for numerical simulation of replacement gas drive compositional model |
| CN108590600A (en) * | 2018-04-26 | 2018-09-28 | 中国石油天然气股份有限公司 | CO (carbon monoxide)2Optimization design method of well killing system of flooding injection and production well |
| CN108593190A (en) * | 2018-06-25 | 2018-09-28 | 青岛科技大学 | A kind of new method determining CO2/ oil-based system minimum miscibility pressures using oil phase hanging drop volume change |
| CN108798614A (en) * | 2017-05-05 | 2018-11-13 | 中国石油化工股份有限公司 | A kind of determination method of CO2 displacement of reservoir oils mixed phase degree |
| CN108952647A (en) * | 2017-05-22 | 2018-12-07 | 中国石油化工股份有限公司 | A method of measuring and calculating the hydrocarbon component influences oil gas minimum miscibility pressure |
| CN110516295A (en) * | 2019-07-17 | 2019-11-29 | 中国石油天然气股份有限公司 | Calculating CO2Numerical simulation method for driving minimum miscible pressure |
| CN110598340A (en) * | 2019-09-18 | 2019-12-20 | 中国石油大学(北京) | Method and device for determining gas injection oil displacement experiment fluid |
| CN110847867A (en) * | 2019-12-12 | 2020-02-28 | 西南石油大学 | Gas injection displacement injection point selection method for tight oil reservoir |
| CN111256900A (en) * | 2020-02-20 | 2020-06-09 | 中国石油大学(北京) | Method and device for determining minimum miscible phase pressure of oil gas |
| CN111305801A (en) * | 2020-03-09 | 2020-06-19 | 中国石油化工股份有限公司 | Carbon dioxide flooding front edge description method |
| CN113075750A (en) * | 2020-01-03 | 2021-07-06 | 中国石油天然气股份有限公司 | Method for determining minimum miscible pressure of carbon dioxide and formation crude oil |
| CN114562242A (en) * | 2022-02-28 | 2022-05-31 | 西南石油大学 | Method for determining miscible mechanism of injected gas and crude oil |
| CN115935674A (en) * | 2022-12-20 | 2023-04-07 | 中国石油大学(北京) | Based on CO 2 Multiphase band discrimination method for time-space change characteristics of reservoir displacement fluid |
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| CN106437640A (en) * | 2016-10-19 | 2017-02-22 | 中国石油化工股份有限公司 | Low-permeability reservoir CO2 and N2 mixed oil displacement method |
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| CN107066672A (en) * | 2017-01-17 | 2017-08-18 | 中海石油(中国)有限公司 | A kind of method for numerical simulation of replacement gas drive compositional model |
| CN106872594A (en) * | 2017-02-16 | 2017-06-20 | 中国石油大学(华东) | CO in one kind test saturated oils porous media2The method of concentration distribution and diffusion coefficient |
| CN106884635A (en) * | 2017-03-03 | 2017-06-23 | 中国石油大学(北京) | Low, the extra-low permeability oil reservoirs CO of one kind2Drive the assay method of minimum miscibility pressure |
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| CN108952647A (en) * | 2017-05-22 | 2018-12-07 | 中国石油化工股份有限公司 | A method of measuring and calculating the hydrocarbon component influences oil gas minimum miscibility pressure |
| CN108590600A (en) * | 2018-04-26 | 2018-09-28 | 中国石油天然气股份有限公司 | CO (carbon monoxide)2Optimization design method of well killing system of flooding injection and production well |
| CN108590600B (en) * | 2018-04-26 | 2020-10-02 | 中国石油天然气股份有限公司 | CO (carbon monoxide)2Optimization design method of well killing system of flooding injection and production well |
| CN108593190B (en) * | 2018-06-25 | 2023-12-19 | 青岛科技大学 | Novel method for determining minimum miscible pressure of CO 2/oil phase system by utilizing oil phase hanging drop volume change |
| CN108593190A (en) * | 2018-06-25 | 2018-09-28 | 青岛科技大学 | A kind of new method determining CO2/ oil-based system minimum miscibility pressures using oil phase hanging drop volume change |
| CN110516295A (en) * | 2019-07-17 | 2019-11-29 | 中国石油天然气股份有限公司 | Calculating CO2Numerical simulation method for driving minimum miscible pressure |
| CN110516295B (en) * | 2019-07-17 | 2021-09-28 | 中国石油天然气股份有限公司 | Calculating CO2Numerical simulation method for driving minimum miscible pressure |
| CN110598340A (en) * | 2019-09-18 | 2019-12-20 | 中国石油大学(北京) | Method and device for determining gas injection oil displacement experiment fluid |
| CN110598340B (en) * | 2019-09-18 | 2020-09-01 | 中国石油大学(北京) | Method and device for determining gas injection oil displacement experiment fluid |
| CN110847867A (en) * | 2019-12-12 | 2020-02-28 | 西南石油大学 | Gas injection displacement injection point selection method for tight oil reservoir |
| CN110847867B (en) * | 2019-12-12 | 2020-08-25 | 西南石油大学 | Gas injection displacement injection point selection method for tight oil reservoir |
| CN113075750A (en) * | 2020-01-03 | 2021-07-06 | 中国石油天然气股份有限公司 | Method for determining minimum miscible pressure of carbon dioxide and formation crude oil |
| CN113075750B (en) * | 2020-01-03 | 2023-07-25 | 中国石油天然气股份有限公司 | Method for determining minimum miscible pressure of carbon dioxide and crude oil in stratum |
| CN111256900A (en) * | 2020-02-20 | 2020-06-09 | 中国石油大学(北京) | Method and device for determining minimum miscible phase pressure of oil gas |
| CN111305801A (en) * | 2020-03-09 | 2020-06-19 | 中国石油化工股份有限公司 | Carbon dioxide flooding front edge description method |
| CN111305801B (en) * | 2020-03-09 | 2021-12-14 | 中国石油化工股份有限公司 | Carbon dioxide flooding front edge description method |
| CN114562242B (en) * | 2022-02-28 | 2023-05-12 | 西南石油大学 | Method for determining miscible mechanism of injected gas and crude oil |
| CN114562242A (en) * | 2022-02-28 | 2022-05-31 | 西南石油大学 | Method for determining miscible mechanism of injected gas and crude oil |
| CN115935674A (en) * | 2022-12-20 | 2023-04-07 | 中国石油大学(北京) | Based on CO 2 Multiphase band discrimination method for time-space change characteristics of reservoir displacement fluid |
| CN115935674B (en) * | 2022-12-20 | 2024-03-12 | 中国石油大学(北京) | Based on CO 2 Multiphase zone discrimination method for space-time change characteristics of oil displacement reservoir fluid |
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