CN100419208C - Multi-block equal-fluidity energy-gathering parallel synchronous oil displacement method for heterogeneous oil reservoir - Google Patents
Multi-block equal-fluidity energy-gathering parallel synchronous oil displacement method for heterogeneous oil reservoir Download PDFInfo
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- 230000001360 synchronised effect Effects 0.000 title claims abstract description 7
- 238000011549 displacement method Methods 0.000 title abstract 2
- 238000006073 displacement reaction Methods 0.000 claims abstract description 39
- 239000012530 fluid Substances 0.000 claims abstract description 35
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 35
- 229920000642 polymer Polymers 0.000 claims abstract description 12
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 11
- 238000000034 method Methods 0.000 claims description 24
- 230000035699 permeability Effects 0.000 claims description 23
- 238000002347 injection Methods 0.000 claims description 19
- 239000007924 injection Substances 0.000 claims description 19
- 230000007062 hydrolysis Effects 0.000 claims description 9
- 238000006460 hydrolysis reaction Methods 0.000 claims description 9
- 229920002401 polyacrylamide Polymers 0.000 claims description 9
- 239000007863 gel particle Substances 0.000 claims description 2
- 230000002349 favourable effect Effects 0.000 abstract 1
- 238000001179 sorption measurement Methods 0.000 abstract 1
- 230000009466 transformation Effects 0.000 abstract 1
- 239000003921 oil Substances 0.000 description 57
- 230000000694 effects Effects 0.000 description 8
- 238000002474 experimental method Methods 0.000 description 6
- 238000011084 recovery Methods 0.000 description 6
- 238000004088 simulation Methods 0.000 description 6
- 241000237858 Gastropoda Species 0.000 description 5
- 230000001186 cumulative effect Effects 0.000 description 4
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- 239000011435 rock Substances 0.000 description 4
- 230000015572 biosynthetic process Effects 0.000 description 3
- 238000009826 distribution Methods 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 239000006260 foam Substances 0.000 description 2
- 238000009533 lab test Methods 0.000 description 2
- 239000010410 layer Substances 0.000 description 2
- 239000011148 porous material Substances 0.000 description 2
- 230000033764 rhythmic process Effects 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- 239000002981 blocking agent Substances 0.000 description 1
- 239000010779 crude oil Substances 0.000 description 1
- 230000007423 decrease Effects 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 239000008398 formation water Substances 0.000 description 1
- 239000011229 interlayer Substances 0.000 description 1
- 239000003350 kerosene Substances 0.000 description 1
- 230000007774 longterm Effects 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- VIKNJXKGJWUCNN-XGXHKTLJSA-N norethisterone Chemical compound O=C1CC[C@@H]2[C@H]3CC[C@](C)([C@](CC4)(O)C#C)[C@@H]4[C@@H]3CCC2=C1 VIKNJXKGJWUCNN-XGXHKTLJSA-N 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 239000012266 salt solution Substances 0.000 description 1
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Abstract
The present invention discloses a multi-section equal-fluidity energy-gathering parallel synchronous oil displacement method for heterogeneous oil reservoirs. Firstly, according to water adsorption ability, a heterogeneous oil reservoir is divided into a plurality of sections; then, the fluidity of oil displacement agent is selected, fluidity of each section of the oil reservoir is maintained to be equal, and the fluidity of the oil displacement agent needed in each oil reservoir is calculated according to fluidity = the permeation rate of an oil reservoir / fluid viscosity. Next, polymer is selected to prepare fluid with corresponding viscosity, and a combined section is formed from sub sections with different viscosity; finally, sub sections from high viscosity to low viscosity are orderly injected into the oil reservoir to accomplish oil displacement. With the characteristics of transformation from integrated oil displacement to separated oil displacement, low displacement resistance, high partial pressure difference on energy-gathering sections, high driving pressure difference, high displacement efficiency and little displacement agent consumption, the present invention is favorable to displacement fluid to change direction, increase propagation volume, as well as reduce ineffective water cycle.
Description
Technical field:
The present invention relates to field of petroleum exploitation, be specifically related to a kind of flooding method non-homogeneous pay.
Background technology:
Be subjected to oil reservoir depositional environment and condition effect, oil reservoir in the plane and the Permeability Distribution heterogeneity vertically, for example the Daqing oil field longtitudinal dispersion rate coefficient of variation mostly is about 0.65.In the waterflooding extraction process, inject the water major part and enter the high permeability zones territory, washed away by long-term injecting water, non-homogeneity is even more serious, and the invalid circulation of injection water is serious.Be the oil reservoir remaining oil of further taping the latent power, polymer displacement of reservoir oil has successively been carried out in the oil field, the ternary chemical flooding, and foam flooding, poly-driving+displacement of reservoir oil modes such as deep profile controlling have been received the reasonable effect of taping the latent power, but oil displacement efficiency still not high (table 1).From statistical form, can see: the minimum moisture time occurs late more, and the effect of taping the latent power is good more.But the minimum moisture time of above-mentioned technology all is no more than 0.4 times voidage, still has a large amount of non-available water circulating phenomenons.
The table 1 measure effect statistical form of taping the latent power
| The mode of taping the latent power | Improve recovery ratio (water drive relatively) | Minimum moisture (PV) |
| Polymer flooding | 8-14％ | 0.2 |
| The ternary chemical flooding | 20-24％ | 0.3 |
| Foam flooding | 25-35％ | 0.37 |
| Poly-driving+the volume expansion grain profile control | 10-16％ | 0.25 |
Summary of the invention:
The object of the present invention is to provide mobility such as a kind of non-homogeneous pay, layer cohesive energy, with the method for the parallel synchronous multiple blocking agent water blockoff of the multistage plug displacement of reservoir oil, to reduce the non-available water circulation, improve the effect of taping the latent power.
The invention provides the synchronous flooding method of a kind of non-homogeneous pay multi-block equal-fluidity energy-gathering parallel, may further comprise the steps:
Step 1: according to the water absorbing capacity size, non-homogeneous pay is divided into plurality of sections, obtains each section permeability K
iWith each section thickness H
iNumerical value;
Step 2: selected oil displacement agent fluid mobility, and keep each section of oil reservoir fluid mobility to equate, utilize formula one to calculate the fluid viscosity of required oil displacement agent in each oil reservoir;
Fluid mobility=reservoir permeability K
i/ fluid viscosity formula one
Step 3: each section fluid viscosity numerical value selective polymer that calculates according to step 2 is made into the fluid of corresponding viscosity, utilizes formula two to calculate the injection rate Q of each viscosity fluid
i, form combined slug by the sub-slug of different viscosities;
(Q
1/ H
1): (Q
2/ H
2): ...: (Q
n/ H
n)=1: 2: ...: n formula two
Wherein: Q
iI=1 ... n is permeability each section injection rate from high to low,
H
iI=1 ... n is permeability each section thickness from high to low,
Q=Q
1+ Q
2+ ... + Q
n, Q is the total injection rate of slug;
Step 4: from high viscosity to low viscosity each sub-slug is injected oil reservoir successively and implement the displacement of reservoir oil.
In the described flooding method, described fluid mobility is at 0.1-5.0 μ m
2/ Pa.s.
In the described flooding method, described oil displacement agent slug system is according to waiting mobility formulated in combination.In the described flooding method, described combined slug is divided into many groups, and the consumption of every group of combined slug neutron slug is all identical with fluid viscosity.In the described flooding method, water filling between every group of combined slug.In the described flooding method, after the combined slug displacement of reservoir oil, with follow-up slug or water drive to moisture 98%.In the described flooding method, described polymer is hydrolysis polyacrylamide polymer, hydrolysis polyacrylamide gel particle or hydrolysis polyacrylamide flow-gel.
In the described flooding method, the total injection rate Q of described slug＜0.5PV, combined slug are the 2-4 group.
The present invention chooses the fluid (or different shut-off capacity) of various flows kinetic viscosity and adopts suitable consumption preparation slug according to oil reservoir longtitudinal dispersion rate size, uninterruptedly injects oil reservoir according to high viscosity to low viscosity order, (being called one group of slug).After inferior high viscosity slug runs into the high viscosity slug, under the effect of pressure reduction, inferior high viscosity slug will enter time permeability interval (or zone) before and after slug; By will inject other group slug successively with quadrat method, available water at interval between the slug group.Form a plurality of three-dimensional plunger walls (cumulative) at earth formation deep.Under certain condition, different slugs can be similar to parallel moving (parallel synchronous) in the wall, thereby form complete relatively multipoint mode piston displacement mode, force injection water to enter more micro pores, improve and inject oil-water displacement efficiency.
Characteristics of the present invention:
(1) transfer the whole displacement of reservoir oil to the discrete displacement of reservoir oil, it is little to drive resistance.
(2) the local pressure reduction of cumulative slug is big, and driving pressure difference is big, helps the changed course of displacement fluid, improves swept volume.
(3) reduce the non-available water circulation, the displacement efficiency height, the displacing agent consumption is few.
Description of drawings:
Fig. 1 is a non-homogeneous pay multistage plug displacement of reservoir oil schematic diagram of the present invention.
Fig. 2 tests moisture curve for numerical simulation;
Fig. 3 is numerical simulation experiment produce oil curve;
Fig. 4 is numerical simulation experiment recovery ratio curve;
Fig. 5 is a physical analogy 1# rock core displacement of reservoir oil curve;
Fig. 6 is a physical analogy 2# rock core displacement of reservoir oil curve.
The specific embodiment:
The present invention mainly solves the problem in the non-homogeneous pay oil recovery.Referring to Fig. 1, because oil reservoir longtitudinal dispersion rate skewness one, there is variation in the longtitudinal dispersion rate, for driving the oil of adopting in each oil reservoir, needs to realize the unanimity of displacement fluid mobility in each oil reservoir by adjusting the fluid and the consumption of different viscosities (and shut-off capacity).
Among the present invention, fluid mobility=reservoir permeability/fluid viscosity.
Therefore, the inventive method at first will be obtained reservoir permeability numerical value, select suitable displacing agent (as polymer) then, according to waiting mobility to be made into, form the slug of different viscosities, uninterruptedly inject oil reservoir (being called a combined slug) by high viscosity to low viscosity order.After inferior high viscosity slug runs into the high viscosity slug, under the effect of pressure reduction, inferior high viscosity slug will enter time permeability interval (or zone) before and after slug; By injecting other combined slug successively with quadrat method, available water at interval between combined slug.Several combined slugs form a plurality of three-dimensional plunger walls at earth formation deep.Under certain condition, different slugs can be similar to parallel moving in the wall, thereby form complete relatively piston displacement mode, force injection water to enter more micro pores, improve and inject oil-water displacement efficiency.
Among the present invention, the slug of different viscosities is sub-slug, uninterruptedly injects oil reservoir by high viscosity to low viscosity order and forms a combined slug.The present invention can also circulate and inject a plurality of combined slugs, and the sub-slug consumption in each combined slug is all identical with fluid viscosity.Among the present invention, the total injection rate Q of slug＜0.5PV, each sub-slug flow driving medium injection rate ratio determines that according to each section thickness the combined slug number is 2-4;
Ratio: (Q
1/ H
1): (Q
2/ H
2): ...: (Q
n/ H
n)=1: 2: ...: n
Wherein: Q
iI=1 ... n is permeability each section injection rate from high to low,
H
iI=1 ... n is permeability each section thickness from high to low,
Q＝Q
1+Q
2+…+Q
n
Embodiment one: numerical simulation
(1) reservoir model
Oil reservoir top depth 1000m, core intersection 6m, positive rhythm distributes.45 ℃ of reservoir temperatures, underground viscosity of crude 8 * 10
-3Pa.s.Original oil-gas ratio: 50, initial oil saturation 80%, residual oil saturation 20%, irreducible water saturation 20%.Stratum reset pressure 10MPa, bubble point pressure 8MPa.The oil reservoir distribution sees Table 2.
Table 2
| Thickness (m) | Permeability (* 10 -3μm 2) | Degree of porosity | |
| The |
2 | 100 | 0.24 |
| The |
2 | 700 | 0.28 |
| |
2 | 2200 | 0.34 |
(2) fluid data
Water proportion is 1, underground viscosity 0.5 * 10
-3Pa.s, oil ratio weighs 0.84, rock density 1.7g/cm
3
Through laboratory experiment, obtain the volume property of slug flow shown in the table 3 data and ooze data mutually with profit shown in the table 4.
Table 3 slug flow volume property data
Table 4 profit oozes data mutually
Sw Krw (water) Kro (oil)
0.2 0 0.6
0.31 0.01 0.36
0.325 0.015 0.3
0.35 0.02 0.23
0.375 0.04 0.15
0.4 0.08 0.12
0.425 0.1 0.1
0.45 0.12 0.06
0.475 0.13 0.04
0.5 0.15 0.03
0.525 0.2 0.025
0.55 0.25 0.018
0.575 0.3 0.012
0.6 0.37 0.006
0.625 0.45 0.003
0.65 0.5 0.002
0.675 0.6 0.001
0.8 0.8 0
In the table 4, Sw: water saturation, Krw: water relative permeability (water), Kro: oil relative permeability
(3) analog result
1, injection process
After water drive moisture 98%, annotate four groups of slug (principal piece plugs, slug host is selected the hydrolysis polyacrylamide for use), every group of slug formed sub-slug by 3 kinds of different viscosities fluids, according to mobility ratio is that 1 selected fluid viscosity is respectively 2000mPa.s, 700mPa.s sub-slug sequence number 1,2,3 is chosen consumption and is respectively 0.006PV, 0.012PV, 0.018PV shown in the 100mpa.s, table 5.Four groups of total fluid volume 0.144PV of slug.Following adopted viscosity 10mPa.s, consumption 0.1PV, the water drive that continues is to moisture 98%.Consumption viscosity sees the following form 5:
Table 5
2, displacement of reservoir oil result:
Moisture curve is seen Fig. 2, and the produce oil curve is seen Fig. 3, and the recovery ratio curve is seen Fig. 4.As can be seen from the figure: cumulative injection is 0.53PV during moisture curve minimum point, has a distinct increment than table 1 numerical value, illustrates that injecting the invalid circulation of water has obtained effective control, and swept volume increases; Produce oil curve oil production increasing degree is bigger, and the remaining oil of can effectively taping the latent power illustrates that the inventive method displacement of reservoir oil increases oil more than 20 times; Oil-recovering rate improves nearly 30 percentage points as can be seen from Figure 4.
Embodiment two: laboratory experiment (physical analogy)
The cuboid rock core that 2 positive rhythms of prepared in laboratory distribute.3cm * 3cm * 30cm, high, normal, basic permeability is respectively 300 * 10
-3μ m
2, 700 * 10
-3μ m
2, 2000 * 10
-3μ m
2, thickness equates.Under 45 ℃ of conditions, saturation experiments salt solution, then saturation simulation oil.Simulated oil viscosity 5 milli handkerchief second, form by recover the oil three factory's crude oil and kerosene allotment of grand celebration.
In the experiment, slug host is selected the hydrolysis polyacrylamide for use, molecular weight 2500 * 10
4Experiment is carried out under 45 ℃ of conditions.Elder generation's water drive continues and annotates two groups of slugs to moisture 98%, and every group of slug is made up of three kinds of different viscosities fluids, and then water drive extremely moisture 98%.Experiment with reference to the concentration of selected each the slug polymer of numerical simulation and experiment condition, inject volume, the experimentation and the displacement of reservoir oil the results are shown in Table 6 and Fig. 5, Fig. 6.
The indoor oil displacement experiment of table 6
Injection rate: 0.3ml/min
Can see that from experimental result the remaining oil effect of taping the latent power is obvious, reaches moisture decline minimum point (identical substantially with the digital-to-analogue result) about cumulative injection 0.5PV, increase nearly 20% percentage point of recovery ratio.
Embodiment three, The field
Lucky 45 sections piece oil areas, 1.03km
2, oil in place: 1,260,000 tons, air permeability: 214.7 * 10
-3μ m
2, the interlayer permeability grade: 20.8～22.7, layer intrinsic permeability is differential: 1.6～1071, formation temperature: 48 ℃.Formation water salinity: 4517mg/L, the water injection well number: 5, the producing well number: 19, day produce oil: 45.9 tons, moisture: 84%.Slug adopts gel, and polymer is the hydrolysis polyacrylamide, molecular weight 1800 * 10
4, inject a combined slug (profile control slug-principal piece plug-take over slug), follow-up water filling, use amount such as table 7:
The movable gel injecting scheme table of table 7
After this slug injected, period of validity increased 40869 tons of oil, improved recovery ratio 6.2%, and input-output ratio is 1: 3.81.
Claims (8)
1. synchronous flooding method of non-homogeneous pay multi-block equal-fluidity energy-gathering parallel may further comprise the steps:
Step 1: according to the water absorbing capacity size, non-homogeneous pay is divided into plurality of sections, obtains each section permeability K
iWith each section thickness H
iNumerical value;
Step 2: selected oil displacement agent fluid mobility, and keep each section of oil reservoir fluid mobility to equate, utilize formula one to calculate the fluid viscosity of required oil displacement agent in each oil reservoir;
Fluid mobility=reservoir permeability K
i/ fluid viscosity formula one
Step 3: each section fluid viscosity numerical value selective polymer that calculates according to step 2 is made into the fluid of corresponding viscosity, utilizes formula two to calculate the injection rate Q of each viscosity fluid
i, form combined slug by the sub-slug of different viscosities;
(Q
1/ H
1): (Q
2/ H
2): ...: (Q
n/ H
n)=1: 2: ...: n formula two
Wherein: Q
iI=1 ... n is permeability each section injection rate from high to low,
H
iI=1 ... n is permeability each section thickness from high to low,
Q=Q
1+ Q
2+ ... + Q
n, Q is the total injection rate of slug;
Step 4: from high viscosity to low viscosity each sub-slug is injected oil reservoir successively and implement the displacement of reservoir oil.
2. according to the described flooding method of claim 1, it is characterized in that described fluid mobility is at 0.1-5.0 μ m
2/ Pa.s.
2. according to the described flooding method of claim 1, it is characterized in that described oil displacement agent slug system is according to waiting mobility formulated in combination.
3. according to claim 1 or 2 or 3 described flooding methods, it is characterized in that described combined slug is divided into many groups, the consumption of every group of combined slug neutron slug is all identical with fluid viscosity.
4. according to the described flooding method of claim 4, it is characterized in that water filling between every group of combined slug.
5. according to the described flooding method of claim 4, it is characterized in that, after the combined slug displacement of reservoir oil, with follow-up slug or water drive to moisture 98%.
6. according to the described flooding method of claim 4, it is characterized in that described polymer is hydrolysis polyacrylamide polymer, hydrolysis polyacrylamide gel particle or hydrolysis polyacrylamide flow-gel.
8. according to the described flooding method of claim 4, it is characterized in that the total injection rate Q of described slug＜0.5PV, combined slug are the 2-4 group.
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| CN100419208C true CN100419208C (en) | 2008-09-17 |
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| CN102619492A (en) * | 2012-02-23 | 2012-08-01 | 中国石油天然气股份有限公司 | Polymer flooding alternate injection method for heterogeneous reservoir |
| CN104100224B (en) * | 2013-04-03 | 2016-12-28 | 中国石油天然气股份有限公司 | Oil well water plugging method |
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| CN103321621B (en) * | 2013-06-24 | 2016-12-28 | 大庆大华宏业石油工程技术有限公司 | Viscous crude wedge shape viscosity slug oil displacement method |
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| CN106089168A (en) * | 2016-06-27 | 2016-11-09 | 烟台智本知识产权运营管理有限公司 | A kind of method of medium to high permeable oil reservoir integral profile control |
| CN105971550A (en) * | 2016-06-27 | 2016-09-28 | 烟台智本知识产权运营管理有限公司 | Profile control method for medium-and-high-permeability reservoir |
| CN106703768B (en) * | 2016-11-29 | 2019-02-12 | 中国海洋石油集团有限公司 | A kind of determination method of simulation high-concentration and low-concentration polymer flooding alternating injection timing |
| CN111734374B (en) * | 2020-08-01 | 2022-06-14 | 西南石油大学 | Associative polymer combination oil displacement method for greatly improving heterogeneous oil reservoir recovery ratio |
| CN113029908B (en) * | 2021-03-16 | 2021-11-26 | 中国石油大学(华东) | Laboratory measurement method for compact reservoir saturation index |
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