CN107130949A - Deep-layer heavy crude CO_2 stimulation injection process phase-state change method of testing - Google Patents
Deep-layer heavy crude CO_2 stimulation injection process phase-state change method of testing Download PDFInfo
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- CN107130949A CN107130949A CN201610105074.0A CN201610105074A CN107130949A CN 107130949 A CN107130949 A CN 107130949A CN 201610105074 A CN201610105074 A CN 201610105074A CN 107130949 A CN107130949 A CN 107130949A
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- 238000002347 injection Methods 0.000 title claims abstract description 79
- 239000007924 injection Substances 0.000 title claims abstract description 79
- 238000000034 method Methods 0.000 title claims abstract description 49
- 230000008859 change Effects 0.000 title claims abstract description 48
- 230000008569 process Effects 0.000 title claims abstract description 40
- 230000000638 stimulation Effects 0.000 title claims abstract description 27
- 238000010998 test method Methods 0.000 title claims abstract description 25
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims abstract description 188
- 229910002092 carbon dioxide Inorganic materials 0.000 claims abstract description 94
- 239000001569 carbon dioxide Substances 0.000 claims abstract description 93
- 230000009467 reduction Effects 0.000 claims abstract description 29
- 238000003860 storage Methods 0.000 claims abstract description 21
- 238000009792 diffusion process Methods 0.000 claims abstract description 9
- 230000009466 transformation Effects 0.000 claims abstract description 7
- 239000007788 liquid Substances 0.000 claims description 25
- 239000000243 solution Substances 0.000 claims description 18
- 239000003795 chemical substances by application Substances 0.000 claims description 16
- 238000012360 testing method Methods 0.000 claims description 11
- 238000005259 measurement Methods 0.000 claims description 8
- 238000004519 manufacturing process Methods 0.000 claims description 7
- 238000013461 design Methods 0.000 claims description 5
- 239000003638 chemical reducing agent Substances 0.000 claims description 4
- 239000002131 composite material Substances 0.000 claims description 3
- 150000001875 compounds Chemical class 0.000 claims description 3
- 238000002513 implantation Methods 0.000 claims description 3
- 230000035699 permeability Effects 0.000 claims description 3
- GCNLQHANGFOQKY-UHFFFAOYSA-N [C+4].[O-2].[O-2].[Ti+4] Chemical compound [C+4].[O-2].[O-2].[Ti+4] GCNLQHANGFOQKY-UHFFFAOYSA-N 0.000 claims description 2
- 230000001603 reducing effect Effects 0.000 abstract description 6
- 229960004424 carbon dioxide Drugs 0.000 description 71
- 239000003921 oil Substances 0.000 description 30
- 239000007789 gas Substances 0.000 description 8
- 238000005553 drilling Methods 0.000 description 5
- 239000012530 fluid Substances 0.000 description 5
- 238000011084 recovery Methods 0.000 description 4
- 238000004088 simulation Methods 0.000 description 4
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 3
- 229910052799 carbon Inorganic materials 0.000 description 3
- 239000010779 crude oil Substances 0.000 description 3
- 238000002474 experimental method Methods 0.000 description 3
- 239000000295 fuel oil Substances 0.000 description 3
- 239000004530 micro-emulsion Substances 0.000 description 3
- 241000790917 Dioxys <bee> Species 0.000 description 2
- GWEVSGVZZGPLCZ-UHFFFAOYSA-N Titan oxide Chemical compound O=[Ti]=O GWEVSGVZZGPLCZ-UHFFFAOYSA-N 0.000 description 2
- 230000005540 biological transmission Effects 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 238000005065 mining Methods 0.000 description 2
- 230000003014 reinforcing effect Effects 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 239000007864 aqueous solution Substances 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 229910002090 carbon oxide Inorganic materials 0.000 description 1
- 238000000205 computational method Methods 0.000 description 1
- 238000013500 data storage Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 230000001965 increasing effect Effects 0.000 description 1
- 238000012544 monitoring process Methods 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 238000005457 optimization Methods 0.000 description 1
- 238000010992 reflux Methods 0.000 description 1
- 230000002269 spontaneous effect Effects 0.000 description 1
- 239000004408 titanium dioxide Substances 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
- 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
-
- 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
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
- Y02P90/00—Enabling technologies with a potential contribution to greenhouse gas [GHG] emissions mitigation
- Y02P90/70—Combining sequestration of CO2 and exploitation of hydrocarbons by injecting CO2 or carbonated water in oil wells
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- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Physics & Mathematics (AREA)
- Fluid Mechanics (AREA)
- Environmental & Geological Engineering (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Chemical & Material Sciences (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Geophysics (AREA)
- Testing Resistance To Weather, Investigating Materials By Mechanical Methods (AREA)
Abstract
The present invention provides a kind of deep-layer heavy crude CO_2 stimulation injection process phase-state change method of testing, and this method includes：Step 1, choose deep-layer heavy crude carbon dioxide viscosity reduction to handle up well, below the well head of carbon dioxide injection tubing string, in the middle part of tubing string and short connection type storage temperature pressure gauge is installed in oil reservoir position；Step 2, thinner and carbon dioxide are injected by certain injection rate slug formula, then boils in a covered pot over a slow fire well, determine the temperature, pressure of carbon dioxide in injection and stewing well process tubing string；Step 3, stewing well terminates, and acts carbon dioxide injection tubing string and short connection type storage temperature pressure gauge, reads temperature, pressure data；Step 4, according to phase transformation theory plate of the carbon dioxide with temperature, pressure change, draw carbon dioxide in injection process pit shaft along journey phase-state change.The deep-layer heavy crude CO_2 stimulation injection process phase-state change method of testing ensures to reach that supercriticality enters oil reservoir, and the diffusion for improving viscous crude CO_2 stimulation well involves ability and viscosity reducing effect.
Description
Technical field
The present invention relates to oil field development technical field, a kind of deep-layer heavy crude CO_2 stimulation injection process is especially related to
Phase-state change method of testing.
Background technology
It is high that deep-layer heavy crude reservoir buries depth, viscosity, causes that mobility is low, oil well amount liquid is low, water injection pressure is high, conventional water drive
How to improve rate of oil production during exploitation and recovery ratio is the problem of receiving much concern in oil exploitation.Such viscous crude in the prior art
The cold following patent document of adopting of viscosity reduction is disclosed.
Chinese patent CN201410049692, discloses a kind of hypotonic viscous crude reinforcing viscosity reducing process of ultra deep, party's normal direction well
Be continuously injected into oil-soluble viscosity reducer in cylinder, squeeze into liquid carbon dioxide, be then continuously injected into pit shaft high temperature antiexpansion and
The viscosity of crude of the hypotonic heavy crude reservoir of ultra deep can be greatly lowered in steam, opening well and making production.
Chinese patent CN201210202121, discloses one kind and is applied to the cold mining method of mid-deep strata low-permeability heavy oil reservoir chemistry,
This method chooses mid-deep strata low-permeability heavy oil reservoir, alternately injection microemulsion viscosity reduction system+liquid carbon dioxide, and microemulsion will
Crude oil peels off into the oil droplet of surface hydrophilic, and viscous crude is in the spontaneous diffusion in system aqueous solution surface；Carbon dioxide has viscosity reduction energization
Effect, and expand microemulsion viscosity reduction radius, by synergy, improve yield and recovery ratio.
Chinese patent CN201210093291, discloses the control device of phase in supercritical carbon dioxide bored shaft, pressure
Force snesor, temperature sensor and mass flowmenter are arranged at pit shaft entrance and exit, in real time monitoring well head carbon dioxide
The temperature and pressure of drilling fluid, control signal is sent by industrial computer control software system, to wellhead back pressure control system and
Heat-exchange device is controlled and adjusted in real time, then recalculate obtain shaft bottom supercritical carbon dioxide drilling fluid pressure,
Temperature, untill meeting above-critical state criterion, and then ensures the carbon dioxide drilling fluid in shaft bottom all the time in super
Critical state state.
Chinese patent CN201010255637, discloses test method for wellbore multiphase flow under supercritical condition, is related to one kind
Test method for wellbore multiphase flow under supercritical condition.Its technical scheme is：Requirement is reached by temperature controller control temperature
When, the high-pressure flow liquid of rated discharge is provided with high-pressure hydraulic pump, flow controller, the experiment circulation of liquid is formed；
Gases at high pressure are provided by high-pressure compressor, high pressure gas holder, drier, gas flow controller, flow through gas-liquid two-phase
Blender, high pressure pit shaft, reflux pipeline, knockout drum, formation circulation；Protected by controlling back pressure to realize in pit shaft
Rated pressure is held, gas is flowed at supercritical conditions.And then gas can be studied under critical and super critical condition in well
Flow behavior in cylinder, sets up pit shaft multiphase flow dynamic mechanics model and computational methods, predicts pit shaft multiphase flowing pressure, can
Realize that HTHP is critical or simulated experiment of pit shaft gas-liquid polyphase flow phenomenon under super critical condition.Can be three high oil gas fields
Wellbore pressure Predicting Technique, MPD technologies and well control technique etc. provide technical support.
Disclosed in above-mentioned prior art is all carbon dioxide thermal recovery, it is cold adopt the method that aspect improves heavy oil development effect,
And the control of supercritical carbon dioxide drilling fluid phase and indoor simulation device, the method for testing of existing carbon dioxide phase,
All it is temperature, the pressure change that carbon dioxide is determined using indoor simulation device, carbon dioxide is drawn according to theoretical plate
Phase, it is impossible to carbon dioxide phase-state change in the pit shaft in the actual measurement injection process in scene, be this we have invented deep layer
The method of testing of viscous crude CO_2 stimulation injection process phase-state change, solves above technical problem.
The content of the invention
It is an object of the invention to provide a kind of optimization design injection rate and pressure and other parameters, it is ensured that reaches that supercriticality is entered
Enter oil reservoir, the diffusion for improving viscous crude CO_2 stimulation well involves the deep-layer heavy crude CO_2 stimulation of ability and viscosity reducing effect
Injection process phase-state change method of testing.
The purpose of the present invention can be achieved by the following technical measures：Deep-layer heavy crude CO_2 stimulation injection process phase becomes
Change method of testing, the deep-layer heavy crude CO_2 stimulation injection process phase-state change method of testing includes：Step 1, choose deep
Layer viscous crude carbon dioxide viscosity reduction is handled up well, pacifies below the well head of carbon dioxide injection tubing string, in the middle part of tubing string with oil reservoir position
Fill short connection type storage temperature pressure gauge；Step 2, thinner and carbon dioxide are injected by certain injection rate slug formula, then
Stewing well, determines the temperature, pressure of carbon dioxide in injection and stewing well process tubing string；Step 3, stewing well terminates, and acts titanium dioxide
Carbon injection string and short connection type storage temperature pressure gauge, read temperature, pressure data；Step 4, according to carbon dioxide with temperature,
The phase transformation theory plate of pressure change, draw carbon dioxide in injection process pit shaft along journey phase-state change.
The purpose of the present invention can be also achieved by the following technical measures：
The deep-layer heavy crude CO_2 stimulation injection process phase-state change method of testing is additionally included in after step 4, lower oil-extracting pump
Flow string, production of recovering the oil.
In step 1, reservoir depth >=2000m, permeability >=50 × 10 are chosen-3um2, oil reservoir gross thickness >=3.0m, only always
The deep-layer heavy crude reservoir of thickness ratio >=0.3, carries out carbon dioxide composite viscosity reducer and handles up, in the well of carbon dioxide injection tubing string
Mouth is following, short connection type storage temperature pressure gauge is installed at tubing string middle part and oil reservoir position.
In step 1,400m, 1300m and oil reservoir position 2241m in the middle part of tubing string below the well head of carbon dioxide injection tubing string
3 short connection type storage temperature pressure gauges, setting measurement point interval time 600s install in place, and open test switch.
In step 2, the water-soluble self-diffusion viscosity reduction agent solution 600t of design segments plug alternating implantation quality concentration 0.06% and
Liquid carbon dioxide 150t carries out compound throughput, and specific slug is to be implanted sequentially viscosity reduction agent solution 150t, liquid carbon dioxide
50t, viscosity reduction agent solution 150t, liquid carbon dioxide 50t, viscosity reduction agent solution 150t, liquid carbon dioxide 50t and thinner
Solution 150t, is injected with plunger pump according to 12t/h injection rate, then boils in a covered pot over a slow fire well 7 days；Storage temperature pressure gauge presses 600s
Time interval, the temperature, pressure of viscosity reduction agent solution and carbon dioxide changes in pit shaft when automatic record injection process and stewing well.
In step 4, by optimizing injection rate, it is ensured that when carbon dioxide enters oil reservoir, temperature is more than 31.2 DEG C, pressure
More than 7.28MPa, to reach that supercriticality enters oil reservoir.
The deep-layer heavy crude CO_2 stimulation injection process phase-state change method of testing, by the temperature pressure installed in injection string
Temperature, the pressure change of power meter actual test carbon dioxide injection process, draw carbon dioxide along journey phase-state change, it is excellent
Change design injection rate and pressure and other parameters, it is ensured that reach that supercriticality enters oil reservoir, improve viscous crude CO_2 stimulation
The diffusion of well involves ability and viscosity reducing effect.The invention has the characteristics that：
1. strengthen steam thermal recovery from deep-layer heavy crude carbon dioxide or the reinforcing cold mining method of thinner is different, they are to utilize dioxy
Change the characteristics of carbon dissolves viscosity reduction in viscous crude, improve steam and the cold viscosity reducing effect for adopting thinner；And deep-layer heavy crude of the present invention
The method of testing of CO_2 stimulation injection process phase-state change, is, along journey phase-state change, to optimize by test carbon dioxide
Injection rate and pressure, it is ensured that carbon dioxide reaches that supercriticality enters oil reservoir, play its density under the state and are bordering on liquid
Body, viscosity is bordering on gas, and diffusion coefficient is 100 times of liquid, the characteristics of the great increase of the ability of dissolving crude oil viscosity reduction, shows
Write the viscosity reduction and oil increasing effect for improving viscous crude；
2. it is different from the control device of phase in supercritical carbon dioxide bored shaft, its pressure sensor and TEMP
Device is arranged at pit shaft entrance and exit, calculates pressure, the temperature for obtaining shaft bottom supercritical carbon dioxide drilling fluid；And this
The method of testing of the deep-layer heavy crude CO_2 stimulation injection process phase-state change of invention, is by installed in carbon dioxide injection
The thermobarometer of below the well head of tubing string, in the middle part of tubing string and oil reservoir position, actual test pit shaft changes along journey temperature, pressure,
Draw the phase-state change of carbon dioxide；
3. different from supercritical carbon dioxide pit shaft Multiphase Flow experimental method and simulation test device, they are lab simulations
With flow test state under the conditions of the CO 2 supercritical of test；And the present invention is the live deep-layer heavy crude dioxy of actual test
Change carbon viscosity reduction handle up well pit shaft in carbon dioxide along journey phase.
Brief description of the drawings
Fig. 1 is a specific embodiment of the deep-layer heavy crude CO_2 stimulation injection process phase-state change method of testing of the present invention
Flow chart；
Fig. 2 is a bite deep-layer heavy crude CO_2 stimulation well injection string figure in the specific embodiment of the present invention；
Fig. 3 is short connection type storage temperature pressure gauge schematic diagram in the specific embodiment of the present invention；
Fig. 4 for the present invention a specific embodiment in a bite deep-layer heavy crude handle up well inject pit shaft diverse location carbon dioxide
Temperature, pressure data graphs；
Fig. 5 is phase transformation theory figure of the carbon dioxide in the specific embodiment of the present invention with temperature, pressure change；
Fig. 6 is certain injection rate carbon dioxide in the specific embodiment of the present invention with well depth phase-state change figure；
Fig. 7 is a bite deep-layer heavy crude CO_2 stimulation well completion tubular column figure in the specific embodiment of the present invention.
Embodiment
For enable the present invention above and other objects, features and advantages become apparent, it is cited below particularly go out preferred embodiment,
And coordinate shown in accompanying drawing, it is described in detail below.
As shown in figure 1, streams of the Fig. 1 for the deep-layer heavy crude CO_2 stimulation injection process phase-state change method of testing of the present invention
Cheng Tu.
In step 101, choose deep-layer heavy crude carbon dioxide viscosity reduction and handle up well, below the well head of injection string, in the middle part of tubing string
Short connection type storage temperature pressure gauge is installed with oil reservoir position.Flow enters step 102.
In step 102, thinner and carbon dioxide are injected by certain injection rate slug formula, well is then boiled in a covered pot over a slow fire, determine injection and
The temperature, pressure of carbon dioxide in stewing well process tubing string.Flow enters step 103.
In step 103, stewing well terminates, and acts carbon dioxide injection tubing string and short connection type storage temperature pressure gauge, reads temperature
Pressure data.Flow enters step 104.
In step 104, according to phase transformation theory plate of the carbon dioxide with temperature, pressure change, draw in injection process pit shaft
Carbon dioxide along journey phase-state change.Flow enters step 105.
In step 105, lower oil-extracting pump flow string, production of recovering the oil.
In the specific embodiment of the application present invention, include following steps：
In step 1, choose deep-layer heavy crude carbon dioxide viscosity reduction and handle up well, below the well head of injection string, in the middle part of tubing string and
Oil reservoir position is installed by short connection type storage temperature pressure gauge.Choose reservoir depth >=2000m, permeability >=50 × 10-3um2, oil
Layer gross thickness >=3.0m, deep-layer heavy crude reservoir of the net gross thickness than >=0.3 carries out carbon dioxide composite viscosity reducer and handled up, under
Enter carbon dioxide injection tubing string as shown in Figure 2, (400m), tubing string middle part (1300m) below the well head of injection string
3 short connection type storage temperature pressure gauges are installed with oil reservoir position (2241m) place, as shown in figure 3, main by differential temperature survey section
1st, pressure measxurement section 2, wire connection cavity 3, electronic circuit 4, magnetic locator 5, battery 6, dewar bottle 7 and bearing shell 8 are constituted.
Wherein differential temperature survey section 1 is that electronic thermometer is used to measure temperature in tubing string, -30 DEG C of measurement range~150 DEG C, measurement accuracy
± 0.5 DEG C, pressure measxurement section 2 is that electronic pressure gauge is used to measure tubing string internal pressure power, 0~60MPa of measurement range, measurement essence
Degree ± 0.1MPa, wire connection cavity 3 is the wiring of electronics temperature pressure meter and pressure gauge, and electronic circuit 4 is deposited for the data of temperature and pressure
Reservoir, maximum 1,500,000 groups of measuring point number, magnetic locator 5 is positioning tripping in position, and battery 6 is electronic thermometer, electron pressure
Meter and data storage provide power supply, most long time of measuring 300 days, and dewar bottle 7 is the heat-insulated guarantee time of measuring of battery, is held
Pressure shell 8 provides pressure-bearing protection for short connection type storage temperature pressure gauge.According to the short connection type storage temperature pressure of step 101 tripping in
Power meter, setting measurement point interval time 600s, and open test switch.
In step 2, thinner and carbon dioxide are injected by certain injection rate slug formula, well is then boiled in a covered pot over a slow fire, injection is determined and stewing
The temperature, pressure of carbon dioxide in well process tubing string.The water-soluble self-diffusion of design segments plug alternating implantation quality concentration 0.06%
Viscosity reduction agent solution 600t and liquid carbon dioxide 150t carries out compound throughput, and specific slug is to be implanted sequentially viscosity reduction agent solution
150t, liquid carbon dioxide 50t, viscosity reduction agent solution 150t, liquid carbon dioxide 50t, viscosity reduction agent solution 150t, liquid
Carbon dioxide 50t and viscosity reduction agent solution 150t, is injected with plunger pump according to 12t/h injection rate, then boils in a covered pot over a slow fire well 7 days；Deposit
Storing temperature pressure gauge presses 600s time intervals, viscosity reduction agent solution and titanium dioxide in pit shaft when automatic record injection process and stewing well
The temperature, pressure change of carbon.
In step 3, stewing well terminates, and acts carbon dioxide injection tubing string and short connection type storage temperature pressure gauge, reads temperature pressure
Force data.Act carbon dioxide injection tubing string and short connection type storage temperature pressure gauge, read temperature, pressure data as shown in Figure 4.
In step 4, according to phase transformation theory plate of the carbon dioxide with temperature, pressure change, draw two in injection process pit shaft
Carbonoxide along journey phase-state change.According to Copyright@1999ChemicaLogic Corporation Draw with CO2
Tab V1.0 carbon dioxide with temperature, pressure change phase transformation theory plate as shown in figure 5, by optimizing injection rate,
When ensuring that carbon dioxide enters oil reservoir, temperature is more than 7.28MPa more than 31.2 DEG C, pressure, to reach that supercriticality enters
Oil reservoir.Memory type temperature pressure gauge is shown, in injection carbon dioxide process：- 20 DEG C, 26MPa, carbon dioxide at well head
For liquid；- 10 DEG C, 27MPa at 400m in pit shaft, carbon dioxide is liquid；55 DEG C, 40MPa at 1300m in pit shaft,
Carbon dioxide is supercriticality；78 DEG C, 47MPa at the 2241m of oil reservoir position, carbon dioxide is supercriticality；Draw
In injection string carbon dioxide with well depth phase-state change curve, as shown in fig. 6, well cylinder pressure gradually increases with well depth increase
Greatly, and consistently greater than 7.28MPa；Temperature gradually rises with well depth increase in pit shaft, and when well depth is more than 960m, temperature reaches
To 31.2 DEG C, carbon dioxide reaches supercriticality, finally enters oil reservoir with supercriticality, and its density is bordering on liquid,
Viscosity is bordering on gas (0.02-0.08mpa.s), and diffusion coefficient is 100 times of liquid, the great increase of ability of dissolving crude oil,
Significantly improve the viscosity reducing effect of viscous crude.
In step 5, lower oil-extracting pump flow string, production of recovering the oil.Tripping in D44 pumps, pump hang 1700m, as shown in fig. 7, adopting
Oil production.
In the another specific embodiment of the application present invention, below the well head of injection string, in the middle part of tubing string and oil reservoir position
Short connection type light transmission thermobarometer is installed, ground monitors temperature, pressure data variation in pit shaft, regulation injection speed in real time
Degree, it is ensured that carbon dioxide enters oil reservoir with temperature more than the supercriticality that 31.2 DEG C, pressure are more than 7.28MPa.This method
Temperature, pressure can be monitored in pit shaft intuitively, in real time to change, but short connection type light transmission thermobarometer cost it is high, without
Ji.
Claims (6)
1. deep-layer heavy crude CO_2 stimulation injection process phase-state change method of testing, it is characterised in that the deep-layer heavy crude titanium dioxide
Carbon injection process phase-state change method of testing of handling up includes：
Step 1, choose deep-layer heavy crude carbon dioxide viscosity reduction to handle up well, below the well head of carbon dioxide injection tubing string, in the middle part of tubing string
Short connection type storage temperature pressure gauge is installed with oil reservoir position；
Step 2, thinner and carbon dioxide are injected by certain injection rate slug formula, then boils in a covered pot over a slow fire well, determine injection and stewing well process
The temperature, pressure of carbon dioxide in tubing string；
Step 3, stewing well terminates, and acts carbon dioxide injection tubing string and short connection type storage temperature pressure gauge, reads temperature, pressure data；
Step 4, according to phase transformation theory plate of the carbon dioxide with temperature, pressure change, carbon dioxide in injection process pit shaft is drawn
Along journey phase-state change.
2. deep-layer heavy crude CO_2 stimulation injection process phase-state change method of testing according to claim 1, its feature exists
In the deep-layer heavy crude CO_2 stimulation injection process phase-state change method of testing is additionally included in after step 4, lower oil-extracting pump
Flow string, production of recovering the oil.
3. deep-layer heavy crude CO_2 stimulation injection process phase-state change method of testing according to claim 1, its feature exists
In, in step 1, selection reservoir depth >=2000m, permeability >=50 × 10-3um2, oil reservoir gross thickness >=3.0m, only always
The deep-layer heavy crude reservoir of thickness ratio >=0.3, carries out carbon dioxide composite viscosity reducer and handles up, in the well of carbon dioxide injection tubing string
Mouth is following, short connection type storage temperature pressure gauge is installed at tubing string middle part and oil reservoir position.
4. deep-layer heavy crude CO_2 stimulation injection process phase-state change method of testing according to claim 3, its feature exists
In, in step 1,400m, 1300m and oil reservoir position 2241m in the middle part of tubing string below the well head of carbon dioxide injection tubing string
3 short connection type storage temperature pressure gauges, setting measurement point interval time 600s install in place, and open test switch.
5. deep-layer heavy crude CO_2 stimulation injection process phase-state change method of testing according to claim 1, its feature exists
In, in step 2, the water-soluble self-diffusion viscosity reduction agent solution 600t of design segments plug alternating implantation quality concentration 0.06% and
Liquid carbon dioxide 150t carries out compound throughput, and specific slug is to be implanted sequentially viscosity reduction agent solution 150t, liquid carbon dioxide
50t, viscosity reduction agent solution 150t, liquid carbon dioxide 50t, viscosity reduction agent solution 150t, liquid carbon dioxide 50t and thinner
Solution 150t, is injected with plunger pump according to 12t/h injection rate, then boils in a covered pot over a slow fire well 7 days；Storage temperature pressure gauge presses 600s
Time interval, the temperature, pressure of viscosity reduction agent solution and carbon dioxide changes in pit shaft when automatic record injection process and stewing well.
6. deep-layer heavy crude CO_2 stimulation injection process phase-state change method of testing according to claim 1, its feature exists
In in step 4, by optimizing injection rate, it is ensured that when carbon dioxide enters oil reservoir, temperature is more than 31.2 DEG C, pressure
Power is more than 7.28MPa, to reach that supercriticality enters oil reservoir.
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Cited By (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN107893648A (en) * | 2017-12-19 | 2018-04-10 | 北京百利时能源技术股份有限公司 | The cold mining method of heavy crude reservoir carbon dioxide accumulation of energy high pressure viscosity reduction |
| CN108252688A (en) * | 2018-01-08 | 2018-07-06 | 中国地质大学（北京） | Compact oil reservoir CO_2 stimulation influence factor Sensitivity Analysis and its application |
| CN112525944A (en) * | 2020-11-27 | 2021-03-19 | 中国科学院武汉岩土力学研究所 | Multiphase characterization device and method for carbon dioxide micro-displacement |
| CN115726745A (en) * | 2021-08-30 | 2023-03-03 | 中国石油天然气股份有限公司 | Method for determining mass flow of supercritical fluid |
-
2016
- 2016-02-25 CN CN201610105074.0A patent/CN107130949A/en active Pending
Cited By (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN107893648A (en) * | 2017-12-19 | 2018-04-10 | 北京百利时能源技术股份有限公司 | The cold mining method of heavy crude reservoir carbon dioxide accumulation of energy high pressure viscosity reduction |
| CN108252688A (en) * | 2018-01-08 | 2018-07-06 | 中国地质大学（北京） | Compact oil reservoir CO_2 stimulation influence factor Sensitivity Analysis and its application |
| CN112525944A (en) * | 2020-11-27 | 2021-03-19 | 中国科学院武汉岩土力学研究所 | Multiphase characterization device and method for carbon dioxide micro-displacement |
| CN112525944B (en) * | 2020-11-27 | 2022-05-03 | 中国科学院武汉岩土力学研究所 | Multiphase characterization device and method for carbon dioxide micro-displacement |
| CN115726745A (en) * | 2021-08-30 | 2023-03-03 | 中国石油天然气股份有限公司 | Method for determining mass flow of supercritical fluid |
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