CN104329082B - Method for determining high-permeability thick-oil oil reservoir polymer flooding early stage polymer injection transfer occasion - Google Patents
Method for determining high-permeability thick-oil oil reservoir polymer flooding early stage polymer injection transfer occasion Download PDFInfo
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- CN104329082B CN104329082B CN201410577565.6A CN201410577565A CN104329082B CN 104329082 B CN104329082 B CN 104329082B CN 201410577565 A CN201410577565 A CN 201410577565A CN 104329082 B CN104329082 B CN 104329082B
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- 238000002347 injection Methods 0.000 title claims abstract description 39
- 239000007924 injection Substances 0.000 title claims abstract description 39
- 229920000642 polymer Polymers 0.000 title claims abstract description 25
- 238000000034 method Methods 0.000 title claims abstract description 24
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 52
- 239000011435 rock Substances 0.000 claims abstract description 46
- 239000007788 liquid Substances 0.000 claims abstract description 9
- 238000012360 testing method Methods 0.000 claims abstract description 7
- 201000008827 tuberculosis Diseases 0.000 claims description 21
- 230000015572 biosynthetic process Effects 0.000 claims description 3
- 230000001174 ascending effect Effects 0.000 abstract 2
- 238000009738 saturating Methods 0.000 abstract 1
- 239000003921 oil Substances 0.000 description 21
- 238000011084 recovery Methods 0.000 description 10
- 238000002474 experimental method Methods 0.000 description 6
- 238000011160 research Methods 0.000 description 6
- 238000004088 simulation Methods 0.000 description 5
- 238000011161 development Methods 0.000 description 3
- 230000018109 developmental process Effects 0.000 description 3
- 239000000295 fuel oil Substances 0.000 description 3
- 238000004519 manufacturing process Methods 0.000 description 3
- 230000003321 amplification Effects 0.000 description 2
- 238000004458 analytical method Methods 0.000 description 2
- 238000006073 displacement reaction Methods 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 238000005065 mining Methods 0.000 description 2
- 238000003199 nucleic acid amplification method Methods 0.000 description 2
- 230000035699 permeability Effects 0.000 description 2
- 230000032683 aging Effects 0.000 description 1
- 230000003679 aging effect Effects 0.000 description 1
- 239000003153 chemical reaction reagent Substances 0.000 description 1
- 238000012790 confirmation Methods 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 239000010779 crude oil Substances 0.000 description 1
- 238000003306 harvesting Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 230000000630 rising effect Effects 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
Classifications
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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
- 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
-
- 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
- E21B43/20—Displacing by water
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Fodder In General (AREA)
- Geophysics And Detection Of Objects (AREA)
Abstract
The invention discloses a method for determining a high-permeability thick-oil oil reservoir polymer flooding early stage polymer injection transfer occasion. The method comprises the following steps that (1) a rock core physical model is built according to a target high-permeability thick-oil oil reservoir, and in addition, injection water and simulated stratum oil are sequentially used for saturating the rock core physical model; (2) under the oil reservoir conditions, the rock core physical model is subjected to flood pot test, the rock core effluent liquid is collected, and a change curve between the water injection PV number and the rock core effluent liquid mass water content is obtained according to the relationship between the water injection PV number and the rock core effluent liquid mass water content; (3) a fast ascending stage of the rock core effluent liquid mass water content along with the water injection quantity in the change curve is determined, a function relationship formula between the rock core effluent liquid mass water content and the water injection PV number in the ascending stage is built, when the rock core effluent liquid mass water content is 0, and the obtained water injection PV number can be determined. The method has the advantages that simplicity and high speed are achieved, and the thick-oil oil reservoir polymer flooding transfer occasion can be more accurately obtained.
Description
Technical field
The present invention relates to a kind of hypertonic heavy crude reservoir polymer flooding early stage notes the determination method on poly- tuberculosiss opportunity, belong to oil
Processing technique field.
Background technology
Being widely popularized of current technique of polymer flooding, has applied to the exploitation of Bohai Sea sea oil reservoir.Due to by offshore platform
Aging effects, Speeding up development efficiency imperative (Zhang Xiansong, Sun Fu street, Feng Guozhi etc. testing in Bohai heavy oil fields polymer flooding shadow
Ring Elements research and field test [J]. Chinese offshore oil and gas, 2007,19 (1):30-34)；Now current carried out polymer flooding
Early stage notes poly- experimentation and live mining site research all shows, notes poly- opportunity in advance and can not only improve recovery ratio moreover it is possible to shorten
Construction cycle, reduce injection rate.In Bohai Sea SZ36-1 mining site polymer flooding in advance test on tuberculosiss opportunity, with respect to 95%
Under the conditions of High water cut, advance to moisture content 60% tuberculosiss, result of study shows recovery ratio amplification substantially (Wang Chao, Su Yanchun, Zhang Ying
Spring. offshore oilfield early stage notes the poly- research improving recovery ratio and puts into practice [J]. innovative technology, 2011,05：34-36).
For the polymer flooding of heavy crude reservoir is developed, ought to there is relatively optimal note poly- opportunity, with respect to
High water cut tuberculosiss gather, and can increase recovery ratio amplification further, obtain optimal recovery ratio.Scholar utilizes plane physics at present
Model experiment and the Main Means of method for numerical simulation, draw heavy crude reservoir polymer flooding oil reservoir moisture percentage be 0% or
Tuberculosiss poly- best results when relatively low (Jiang Shanshan, Yang Junru, Sun Fu street etc. the research of offshore oilfield polymer injection opportunity and scene should
With [J]. offshore oil, 2009,03 (29):37-42)；Shi Leiting etc. passes through mutually to ooze analysis acquisition Bohai Sea SZ36-1 formation condition
The theoretical optimal tuberculosiss scope of lower polymer flooding, and thought in oil reservoir port of export moisture content by laboratory physical simulation experiment and be
0% about is optimal note poly- opportunity.
Existing research meanses and success are all intended to set up in substantial amounts of physical model data and produced on-site real data
On the basis of carry out, related conclusions can not be obtained real-time, instruct to actual offer the in scene.So needs one can
Quick and accurate method provides for live actual production and instructs.
Content of the invention
It is an object of the invention to provide a kind of hypertonic heavy crude reservoir polymer flooding early stage note the determination method on poly- tuberculosiss opportunity,
The method can be simple and quick, more accurately obtains the tuberculosiss opportunity of heavy crude reservoir polymer flooding, is that polymer flooding of heavy oil produces
Actual development provides tuberculosiss to instruct, it is to avoid obtain tuberculosiss opportunity by the Physical Experiment and numerical simulation of plenty of time, impact
The production development of oil reservoir.
The hypertonic heavy crude reservoir polymer flooding early stage that the present invention provides notes the determination method on poly- tuberculosiss opportunity, walks including following
Suddenly：
(1) rock core physical model is built according to the hypertonic heavy crude reservoir of target, and full with injection water and simulated formation oil successively
With described rock core physical model；
(2) under reservoir conditions, flood pot test is carried out to described rock core physical model, and collect rock core effluent；Root
According to the relation between the injection PV number of water and the quality moisture content of described rock core effluent, obtain the injection PV number of water and described rock
Change curve between the quality moisture content of heart effluent；
The volume that described injection PV number refers to inject the water in described rock core physical model accounts for described rock core physical model
The multiple of total pore size volume, unit is PV；
(3) determine in described change curve, the quality moisture content of described rock core effluent is with the rapid increase rank of water injection rate
Section；Set up in the described rapid increase stage, the function between the injection PV number of the quality moisture content of described rock core effluent and water
Relational expression；According to described functional relation, when the quality moisture content of described rock core effluent is 0, obtain the injection PV number of water,
Being defined as hypertonic heavy crude reservoir polymer flooding early stage notes poly- tuberculosiss opportunity.
Above-mentioned determination method, in step (1), described injection water can build rock core according to the hypertonic heavy crude reservoir of specific target
Physical model is selected.
Above-mentioned determination method, in step (3), described change curve particularly may be divided into three phases, and the first stage is anhydrous
In the oil recovery stage, the quality moisture content of described rock core effluent is 0%；Second stage is the rapid increase stage, and described rock core flows out
The quality moisture content of liquid is with the injection PV number rapid increase of water；Phase III is the quality moisture content of described rock core effluent
Change the stage gradually tended towards stability.
Above-mentioned determination method, in step (3), described rapid increase phase slope can be 1.6～1.9PV-1, described slope
Straight slope for described rapid increase stage whole story end line.
Above-mentioned determination method, in step (3), in described change curve, the described rapid increase stage refers to described rock core
The quality moisture content of effluent rises to for 80% stage from 0.
The hypertonic heavy crude reservoir polymer flooding early stage that the present invention provides notes the determination method on poly- tuberculosiss opportunity, and the method can
Simple and quick, more accurately obtain the tuberculosiss opportunity of heavy crude reservoir polymer flooding, be that the exploitation of polymer flooding of heavy oil produce reality carries
Instruct for tuberculosiss, it is to avoid tuberculosiss opportunity, the production of impact oil reservoir are obtained by the Physical Experiment and numerical simulation of plenty of time
Exploitation.
Brief description
Fig. 1 is the change between PV number and the quality moisture content of rock core effluent for the injection of water in the specific embodiment of the invention
Change curve.
Fig. 2 is 3 different phases in Fig. 1 change curve.
Fig. 3 is the rapid increase stage with water injection rate for the quality moisture content of rock core effluent in Fig. 2.
Fig. 4 is the rapid increase stage, the change curve of injection PV number of the quality moisture content of rock core effluent and water and plan
Close curve.
Specific embodiment
Experimental technique used in following embodiments if no special instructions, is conventional method.
Material used, reagent etc. in following embodiments, if no special instructions, all commercially obtain.
Carry out the research of indoor Physical Experiment by the inventive method, comprise the steps：
(1) oil reservoir first against specified conditions makes physical model, is shown in Table 1：(45mm × 45mm × 300mm is three layers
Heterogeneous body, the coefficient of variation is 0.76, and mean permeability is 2500mD).
Table 1 oil displacement experiment related data
| Parameter type | Parameter value |
| Viscosity of crude, mPa s | 70 |
| Temperature, DEG C | 65 |
| Physical model | 45×45×300 |
| Permeability, mD | 2500 |
| Viscosity of injected water, mPa s | 0.6 |
(2) vacuum saturation water (is put into above-mentioned physical model rock core in injection water, is evacuated with vacuum pump negative pressure 0.1MPa
12h) condition；Become under the conditions of 75 DEG C of temperature flow velocity with 0.1,0.2,0.5,1mL/min flow velocity displacement 16h respectively, 4h, 4h, 2h
Mode saturated oils, after aging 48h, carry out physical simulation experiment flood pot test, the water drive oil under the conditions of obtaining shown in table 1
During water change curve between PV number and the quality moisture content of rock core effluent for the injection, see Fig. 1.
(3) as shown in Fig. 2 the curve of Fig. 1 is divided into three sections, moisture content is 0 section (no water drive oil section), moisture content 0-
(slope is 1.6-1.9PV to 80% section-1) (moisture content rapid increase section), and moisture content 80%-95% (moisture content rising
Steady section).Take moisture content rapid increase section, that is, moisture content generates Fig. 3 for this stage curve of 0-80%.
(4) the rapid increase stage according to Fig. 3, the quality moisture content of rock core effluent is with the change of the injection PV number of water
Change curve, obtain the change curve with the quality moisture content of rock core effluent for the injection PV number of water, as shown in Figure 4.
Injection PV number according to above-mentioned water obtains rock core stream with the change curve of the quality moisture content of rock core effluent, matching
Go out the functional relation between the quality moisture content of liquid and the injection PV number of water：Y=5 × 10-7x3+1×10-5x2+0.000x+
0.130, R2=0.996, the change curve between the two of this functional relation reflection is as shown in Figure 4.
(5) by the functional relation in moisture content rapid increase stage, and combine oil reservoir anhydrous oil recovery section, counter be pushed into oil reservoir
Water drive breaks through section, and that is, during water drive oil breakthrough oil reservoir during x=0, tuberculosiss gather, and obtaining current water injection rate is 0.130PV, that is, be defined as
Optimal tuberculosiss poly- opportunity.
In above-mentioned experimentation, measure the oil recovery factor under different injection amount, result is as shown in table 2.Can by table 2
Know, when reservoir water drive leading edge is up to the port of export, when that is, water injection rate is 0.122PV (moisture content is 0), the final harvesting of crude oil
Rate reaches 49.2%, recovery ratio value highest, and the water injection rate obtaining with confirmation method of the present invention is 0.130PV (moisture content is 0%)
Close to it was demonstrated that the feasibility of the inventive method and credibility.
Table 2 early stage notes the poly- Opportunity Analysis result of poly- different note
| Note poly- opportunity | Ultimate recovery, % |
| Water filling 0.003PV (moisture content 0%) | 44.5 |
| Water filling 0.104PV (moisture content 0%) | 48.3 |
| Water filling 0.122PV (moisture content 0%) | 49.2 |
| Water filling 0.131PV (aqueous 20% about) | 44.9 |
Claims (2)
1. a kind of hypertonic heavy crude reservoir polymer flooding early stage notes the determination method on poly- tuberculosiss opportunity, comprises the steps：
(1) rock core physical model is built according to the hypertonic heavy crude reservoir of target, and successively with injection water and simulated formation oil saturation institute
State rock core physical model；
(2) under reservoir conditions, flood pot test is carried out to described rock core physical model, and collect rock core effluent；According to water
Injection PV number and the quality moisture content of described rock core effluent between relation, obtain the injection PV number of water and described rock core stream
Go out the change curve between the quality moisture content of liquid；
The volume that described injection PV number refers to inject the water in described rock core physical model accounts for the total hole of described rock core physical model
The multiple of gap volume, unit is PV；
(3) determine in described change curve, the quality moisture content of described rock core effluent is with the rapid increase stage of water injection rate；Build
Found the functional relationship in the described rapid increase stage, between the injection PV number of the quality moisture content of described rock core effluent and water
Formula；According to described functional relation, when the quality moisture content of described rock core effluent is 0, obtain the injection PV number of water, that is, really
Being set to hypertonic heavy crude reservoir polymer flooding early stage notes poly- tuberculosiss opportunity；
In described change curve, the quality moisture content that the described rapid increase stage refers to described rock core effluent rises to from 0
80% stage.
2. determination method according to claim 1 it is characterised in that：In step (3), in described change curve, described fast
The slope of fast ascent stage is 1.6～1.9PV-1.
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Families Citing this family (7)
| Publication number | Priority date | Publication date | Assignee | Title |
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| CN105863587B (en) * | 2016-06-01 | 2018-10-16 | 中国海洋石油集团有限公司 | A kind of determination method of polymer flooding alternating injection timing |
| CN106097118A (en) * | 2016-06-08 | 2016-11-09 | 西南石油大学 | A kind of permeability saturation curve determines the method for heavy crude reservoir polymer flooding scope on opportunity |
| CN106050196B (en) * | 2016-06-08 | 2019-03-08 | 西南石油大学 | A kind of Offshore Heavy Oil Field oil reservoir early stage note gathers the determination method on preferable metaideophone opportunity |
| CN106014359B (en) * | 2016-06-08 | 2018-08-24 | 西南石油大学 | A kind of poly- earliest metaideophone opportunity judgment method of sea oil reservoir early stage note |
| CN107869340A (en) * | 2016-09-23 | 2018-04-03 | 中国石油化工股份有限公司 | The system of selection on thick oil well bore viscosity reduction opportunity |
| CN111502616B (en) * | 2019-01-30 | 2022-03-29 | 中国石油天然气股份有限公司 | Method and device for determining water injection parameters and storage medium |
| CN112228055B (en) * | 2020-11-10 | 2024-03-26 | 中国石油天然气股份有限公司 | Method and device for determining conversion time under two-three combined development mode |
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| US3830301A (en) * | 1972-11-16 | 1974-08-20 | Union Oil Co | Miscible flooding process using methane-enriched soluble oil |
| CN101609624A (en) * | 2009-07-11 | 2009-12-23 | 西南石油大学 | A kind of preparation method and application thereof that is used for simulated oil in indoor oil displacement experiment |
| CN102251763A (en) * | 2011-06-03 | 2011-11-23 | 中国石油天然气股份有限公司 | Composite profile control and flooding oil production method for developing heavy oil reservoir by water injection |
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2014
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|---|---|---|---|---|
| US3830301A (en) * | 1972-11-16 | 1974-08-20 | Union Oil Co | Miscible flooding process using methane-enriched soluble oil |
| CN101609624A (en) * | 2009-07-11 | 2009-12-23 | 西南石油大学 | A kind of preparation method and application thereof that is used for simulated oil in indoor oil displacement experiment |
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|---|
| 海上油田注聚合物时机研究及现场应用;蒋珊珊等;《海洋石油》;20090930;第29卷(第3期);37-42 * |
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Address after: 100010 Beijing, Chaoyangmen, North Street, No. 25, No. Co-patentee after: CNOOC research institute limited liability company Patentee after: China Offshore Oil Group Co., Ltd. Address before: 100010 Beijing, Chaoyangmen, North Street, No. 25, No. Co-patentee before: CNOOC Research Institute Patentee before: China National Offshore Oil Corporation |