CN114427374B - Well group cooperative water control method for disconnected solution oil reservoir - Google Patents
Well group cooperative water control method for disconnected solution oil reservoir Download PDFInfo
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- 230000005465 channeling Effects 0.000 claims abstract description 43
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- ZRALSGWEFCBTJO-UHFFFAOYSA-N Guanidine Chemical compound NC(N)=N ZRALSGWEFCBTJO-UHFFFAOYSA-N 0.000 claims description 10
- 230000033558 biomineral tissue development Effects 0.000 claims description 8
- 239000003431 cross linking reagent Substances 0.000 claims description 7
- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonia chloride Chemical compound [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 claims description 6
- 239000011159 matrix material Substances 0.000 claims description 6
- 150000003839 salts Chemical class 0.000 claims description 6
- CHJJGSNFBQVOTG-UHFFFAOYSA-N N-methyl-guanidine Natural products CNC(N)=N CHJJGSNFBQVOTG-UHFFFAOYSA-N 0.000 claims description 5
- SWSQBOPZIKWTGO-UHFFFAOYSA-N dimethylaminoamidine Natural products CN(C)C(N)=N SWSQBOPZIKWTGO-UHFFFAOYSA-N 0.000 claims description 5
- 238000009826 distribution Methods 0.000 claims description 5
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- BTBUEUYNUDRHOZ-UHFFFAOYSA-N Borate Chemical compound [O-]B([O-])[O-] BTBUEUYNUDRHOZ-UHFFFAOYSA-N 0.000 claims description 3
- BPQQTUXANYXVAA-UHFFFAOYSA-N Orthosilicate Chemical compound [O-][Si]([O-])([O-])[O-] BPQQTUXANYXVAA-UHFFFAOYSA-N 0.000 claims description 3
- 239000000654 additive Substances 0.000 claims description 3
- 235000019270 ammonium chloride Nutrition 0.000 claims description 3
- 239000012752 auxiliary agent Substances 0.000 claims description 3
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- ZFXVRMSLJDYJCH-UHFFFAOYSA-N calcium magnesium Chemical compound [Mg].[Ca] ZFXVRMSLJDYJCH-UHFFFAOYSA-N 0.000 claims description 3
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- 230000015784 hyperosmotic salinity response Effects 0.000 claims description 3
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- 229910000278 bentonite Inorganic materials 0.000 claims description 2
- SVPXDRXYRYOSEX-UHFFFAOYSA-N bentoquatam Chemical compound O.O=[Si]=O.O=[Al]O[Al]=O SVPXDRXYRYOSEX-UHFFFAOYSA-N 0.000 claims description 2
- 239000000945 filler Substances 0.000 claims description 2
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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
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
-
- 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)
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- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
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Abstract
The invention relates to a well group collaborative water control method of a broken solution oil reservoir, which comprises a well group identification step and a well group collaborative water control step, wherein oil well type identification is carried out according to geological data, dynamic and static response of the well group and water breakthrough characteristics of the well group in sequence, a bottom water source well, a middle water channeling well and a top water seeing well are identified, the bottom water source well is blocked with high strength, a main channel for rising bottom water is blocked, and water flooding of a near water source well is delayed; medium-strength plugging is carried out on the middle water channeling well, so that a large crack channel is plugged, and water channeling is inhibited; according to the method, oil wells are identified and classified according to the connectivity of well groups, different plugging agents are adopted for plugging at different intensities according to different types of oil wells, the 'single-point scattered plugging' in the prior art is changed to the 'unit integral control', and the scale water control is realized by gradually plugging from low to high according to a water outlet path.
Description
Technical Field
The invention relates to the field of oilfield development, in particular to a well group collaborative water control method for a broken solution oil reservoir.
Background
The Tahe oil field is positioned at the southwest of the Sanya bump of the Tarim basin, the Alkeler bump undergoes multi-stage structural movement to form a large number of karst fracture-cave reservoirs, wherein the carbonate fracture-solution reservoir is an effective oil-gas trap formed by fracture zones in the carbonate rock formation and is formed by deep fractures transformed by multi-stage karst action and various derived structures thereof.
The oil reservoir uses cracks and holes as main seepage storage spaces, the matrix is compact, the seepage storage capacity is basically not possessed, the fracture-hole unit is used as a basic research object in the development process, common oil-water coexistence is adopted in the fracture-hole unit, the fracture-hole unit is broken into strip-shaped development on the plane, the longitudinal multi-stage karst has certain sectionality, but the high-angle fracture development under the construction effect does not possess common layering property, the oil and gas in the initial stage of the reservoir development are usually high in yield, the number of high-water-content wells gradually rises after water breakthrough along with the continuous deep development of an oil field, 236 mouths of the secondary type carbonate rock high-yield wells are counted, the total well number is 14%, the yield is 342 ten thousand tons, the ratio is 60%, the annual influence yield is 56 ten thousand tons after water breakthrough, the average daily influence is 1500 tons, and in order to ensure the integral development effect of the oil field, the water content of the oil well is reduced, and single well water shutoff or well group water injection measures are usually adopted.
And the tower river water shutoff starts from 'fifteen', and with the increase of old well measures, the number of short open hole wells with open hole sections smaller than 30m is increased year by year, and currently, the number of short open hole wells exceeds 150 wells. Because the longitudinal take-over space is small, the difficulty of water shutoff engineering is increased, most oil wells face the problems of short well sections and identical oil-water layers, on one hand, the conventional plugging agent is difficult to adapt to the harsh geological conditions of carbonate reservoirs (the burial depth is 5400-6600 m, the temperature is 120-140 ℃, the mineralization degree is 210-240 g/L), on the other hand, the oil-water selectivity is poor, stratum is easy to be blocked or the effective rate is low (the effective rate is only 41.8% when 55-well water shutoff operations are implemented in the early stage) because the bottom water is easy to be communicated again due to later acidification, and the water shutoff difficulty is extremely high.
The integral water control of domestic oil fields starts in the last century 80, takes integral profile control of heavy oil reservoirs and clastic rock reservoirs as main materials, is mainly applied to victory island/east oil fields, liaohe Jinzhou/cold home oil fields, large harbor oil fields and the like, but the transverse communication relation of fracture-cavity oil reservoirs is not clear, the oil injection well pattern is imperfect, the water injection pressure cone or water flooding effect between well groups is poor, the unidirectional effect and the water channeling phenomenon are increasingly serious, and the traditional method is mainly aimed at optimizing a single well water blocking process or system, and meanwhile, the proposed medicament cannot adapt to the development environment of high temperature and high salt of the Tahe, so that a new water control method aiming at the broken solution oil reservoirs is needed.
Disclosure of Invention
The invention provides a well group collaborative water control method for an intermittent fluid reservoir, which is used for changing from single-point scattered blocking to unit integral control and realizing scale water control by gradually blocking from low to high according to a water outlet path.
The technical scheme of the invention is as follows:
the well group cooperative water control method for the disconnected solution oil reservoir is characterized by comprising the following steps of:
A well group identification step, namely carrying out oil well type identification according to geological data, dynamic and static response of the well group and water breakthrough characteristics of the well group in sequence, identifying a well which is communicated with a water source in the longitudinal direction and is displayed by a deep bead string as a bottom water source well, identifying a well which is communicated with the water source well by a part of crack channels and is characterized by water breakthrough and high water content in middle part as a middle water channeling well, and identifying a well which is far away from the bottom water source well and is positioned high in the well region as a top water finding well;
a well group collaborative water control step, namely injecting a high-strength plugging well plugging agent into the bottom water source well to perform high-strength plugging, plugging a main rising channel of bottom water, and delaying flooding of a near water source well; injecting a medium-strength plugging agent into the middle water channeling well to perform medium-strength plugging, so as to plug a large crack channel and inhibit water channeling; and injecting a weak plugging agent for the top water-looking well according to the water channeling degree of the top water-looking well so as to perform low-strength plugging, and selectively plugging the water channeling channel.
Preferably, in the well group identification step, oil well type identification is performed according to geological data, well group dynamic and static response and well group water-breakthrough characteristics in sequence, and also by combining reserves characteristics, position distribution and stratum profile characteristics.
Preferably, in the well group cooperative water control step, the high-strength plugging well plugging agent is plugged by adopting a rubber particle plugging agent and a high-temperature-resistant gel plugging agent; the medium-strength well plugging agent is plugged by adopting a delayed expansion particle plugging agent, a mineral powder gel plugging agent and a high-temperature gel plugging agent; the weakly plugging agent adopts oil-soluble adhesion particle plugging agent, selective temperature-resistant gel plugging agent and high-temperature gel plugging agent for plugging.
Preferably, in the well group cooperative water control step, the identified oil wells of various types are uniformly divided into three slugs, and the three slugs comprise a front slug, a main slug and a sealing slug, and the components or proportions of the plugging agents injected by the corresponding slugs of the oil wells of various types are different from each other.
Preferably, the components of the injection plugging agent in the corresponding slugs of each type of oil well are respectively as follows:
bottom water source well:
The pre-slug is prepared by adding 1.0% -2.0% of rubber particles into water according to the mass percentage concentration, and then injecting the prepared plugging agent into a stratum with the injection amount of 800-1000 square; the main body slug is prepared into a high-temperature-resistant gel plugging agent with the density of 1.07-1.09/cm 3 and the viscosity of 30-35mpa.s, and the high-temperature-resistant gel plugging agent is injected into a stratum after being prepared, wherein the injection amount is 200-300 square; the sealing slug is prepared by adding 2-5% of ammonium chloride, 5-10% of G-level cement and 0.01-1% of retarder into water according to the mass percentage concentration, and injecting the mixture into a stratum with the injection amount of 5-10;
Middle water channeling well:
The pre-slug is prepared by adding 1.0-2.0% of delayed expansion particles into water according to the mass percentage concentration, and then injecting the prepared plugging agent into a stratum, wherein the injection amount is 100-200 square; preparing a main body slug, namely preparing a mineral powder gel plugging agent with the density of 1.15-1.18/cm 3 and the viscosity of 30-35mpa.s, and injecting the mineral powder gel plugging agent into a stratum after the mineral powder gel plugging agent is prepared, wherein the injection amount is 300-500 square; sealing the slug, preparing a high-temperature gel plugging agent with the density of 1.07-1.09/cm 3 and the viscosity of 30-35mpa.s, and injecting the high-temperature gel plugging agent into a stratum after the high-temperature gel plugging agent is prepared, wherein the injection amount is 50-80 square;
top water well:
the pre-slug is prepared by adding 3.0-5.0% of oil-soluble adhesion particles into water according to the mass percentage concentration, and then injecting the prepared plugging agent into a stratum with the injection amount of 100-300 square; the main body slug is prepared into a selective temperature-resistant gel plugging agent with the density of 1.12-1.14/cm 3, and the plugging agent is injected into a stratum after being prepared, wherein the injection amount is 50-200 square; sealing the slug, preparing high-temperature gel plugging agent with density of 1.07-1.09/cm 3 and viscosity of 30-35mpa.s, and injecting into stratum after preparing, wherein the injection amount is 50-80 square.
Preferably, the rubber particles adopted by the front section of the bottom water source well have a particle density of 1.16-1.19g/cm 3 and a particle size range of <10mm, and keep stable performance and elasticity in 130 ℃;
and/or the high-temperature-resistant gel plugging agent adopted by the bottom water source well main body slug is a monomer or a polymer with temperature resistance and salt resistance, or a cross-linking agent which leads the molecular chain of the plugging agent to be introduced into a ring structure, or a naphthol/urotropine cross-linking agent, is dynamically not glued, and has the glue-forming time of 8-10 hours at 140 ℃ under static state;
and/or mixing the delayed expansion particles adopted by the front section plug of the middle water channeling well with rubber and an additive to form a rubber matrix, adding the dosage of a hydrophilic agent and a calcium-magnesium ion chelating agent into the rubber matrix, constructing a chemical crosslinking network, forming uniform particles with the size of 1-1.5mm, and slowly expanding to 2-3 times of the original volume when meeting water and keeping stable;
and/or the mineral powder gel plugging agent adopted by the main body slug of the middle water channeling well has the characteristics of compressive strength of more than 0.1MPa and dynamic non-thickening for a plurality of hours;
And/or, the oil-soluble adhesion particles adopted by the top water-seeing well front-end slug are formed by adding strength regulator and density regulator serving as auxiliary agents on the basis of resin particles, and the top water-seeing well front-end slug is adhered by water particles under the conditions of 150 ℃ and 21 thousands of mineralization and has specific thermoplasticity and bearing strength;
And/or the selective temperature-resistant gel plugging agent adopted by the top water-meeting well main body slug meets the requirement of forming gel for 3-5 hours at 130 ℃ and forming non-flowing gel, the surface of the inverted gel is slightly deformed, and the salt tolerance is more than 21 ten thousand mineralizations.
Preferably, the retarder employed in the bottom water source well seal slugs is borate or silicate.
Preferably, the main components of the gel plugging agent adopted in the main body slugs of the various oil wells are polysilicone, an activating agent, a retarder and a bentonite filling agent.
Preferably, after three slugs of various oil wells are injected with corresponding plugging agents, the method further comprises displacing slugs, wherein 0.2% of guanidine gum solution 10-side is added into water by the displacing slugs according to the mass percentage concentration, and the displacing fluid is injected to displace the plugging agents to the deep part of the stratum.
Preferably, the displacement fluid is oilfield water, and the use amounts of the bottom water source well, the middle water channeling well and the top water seeing well are respectively 1.5-2.0 times, 1.0-1.5 times and 1.0 times of the sum of the volume of the ground manifold and the volume of the construction string and the volume of the completion casing from the construction string to the artificial lower well.
The beneficial effects of the invention are as follows:
The application provides a well group cooperative water control method for a broken solution oil reservoir, which is mainly characterized in that a well group identification step and a well group cooperative water control step are arranged for well group cooperative water control of a carbonate broken solution oil reservoir, oil well type identification is carried out according to geological data, dynamic-static response of the well group and water-breakthrough characteristics of the well group in sequence, a bottom water source well, a middle water channeling well and a top water-seeing well are identified, the bottom water source well is blocked in a high-strength manner, a main channel for rising of bottom water is blocked, and flooding of a near water source well is delayed; medium-strength plugging is carried out on the middle water channeling well, so that a large crack channel is plugged, and water channeling is inhibited; and (3) carrying out low-strength plugging adjustment on the top water-looking well according to the water channeling degree, selectively plugging the water channeling channel and releasing the potential of residual oil. Based on geological data, taking the dynamic and static response of the well groups and the sequential water-breakthrough characteristic of the well groups into consideration, namely the connectivity of the well groups, the dynamic and static correspondence among the well groups, poor water flooding effect and imperfect well pattern; the well group has the characteristics of water breakthrough in turn, the bottom water rises, shan Jingshui floods, the water in adjacent wells rises, and the water channeling phenomenon exists, namely, the water control of the individual wells is not realized, the connectivity of the well group is considered, the identification of the wells is carried out, the types of the wells are divided, different blocking agent systems are adopted for blocking the wells according to different types, the unit integral control is realized, the cooperative water control of the well group is realized, the single-point scattered blocking in the prior art is converted into the unit integral control of the application, and the large-scale water control is realized by gradually blocking from low to high according to the water outlet path.
The well group cooperative integral water control method provided by the water control treatment thought of the invention has the advantages that the measure is based on the water blocking process, the aim is to increase the yield benefit of the whole fracture-cavity unit in a cooperative manner, the high-strength blocking of the bottom source and the matching blocking adjustment of the well containing water at the middle and upper parts are adopted, the water outlet channel on the whole strip of the broken solution is restrained, the large-scale water control is realized, and the effect of half effort is realized on the later-stage extracting solution and water driving. Meanwhile, the range of stratum conditions is very wide, the temperature of the stratum needing water shutoff is preferably 120-150 ℃, the mineralization degree of underground water is preferably less than or equal to 250000mg/L, the adopted various plugging agents have the characteristics of high temperature resistance, high salt resistance, safety, reliability, low cost and capability of realizing the operation of a fixed pipe column, the water shutoff economic benefit is improved on the basis of fully adapting to the requirements of an intermittent solution oil reservoir, the problem of poor adaptability of the conventional single well water shutoff technology and water injection profile control when being applied to the intermittent solution oil reservoir is solved, the plane is longitudinally adjusted, and the water shutoff is adjusted and displaced, so that the deep source of the carbonate intermittent solution oil reservoir is effectively plugged, the planar oil well water invasion is inhibited, the oil well production effect is improved, the integral production effect of a block is improved, and the method has good development and synergy prospects.
Drawings
FIG. 1 is a schematic diagram of a well group collaborative water control method for an intermittent fluid reservoir of the present invention.
The reference numerals of the present invention are listed below:
a-plugging with low strength; b-medium-strength plugging; c, high-strength plugging.
Detailed Description
For a clearer understanding of the content of the invention, reference will be made to the following detailed description taken in conjunction with the accompanying drawings and examples.
The invention relates to a well group collaborative water control method of a broken solution oil reservoir, which comprises a well group identification step and a well group collaborative water control step, wherein the well group identification step is to carry out oil well type identification according to geological data, well group dynamic and static response, well group water breakthrough characteristics, reserve characteristics, position distribution and stratum profile characteristics, identify a well which is longitudinally communicated with a water source by deep bead string display as a bottom water source well, dynamically identify a forefront well, identify a well which is communicated with the water source well by a part of crack channels and is characterized by later water breakthrough and higher water content as a middle water channeling well, and identify a well which is far away from the bottom water source well and is higher in position in the well region as a top water seeing well; the well group cooperative water control step is to perform high-strength blocking by injecting high-strength blocking well plugging agent into a bottom water source well, so as to block a main rising channel of bottom water and delay flooding of a near water source well; injecting a medium-strength plugging agent into the middle water channeling well to perform medium-strength plugging, so as to plug a large crack channel and inhibit water channeling; and (3) injecting a weak plugging agent for regulating and plugging the top water-looking well according to the water channeling degree of the top water-looking well so as to regulate and plug the water channeling channel with low intensity, selectively plugging the water channeling channel and releasing the potential of residual oil. The plane and longitudinal heterogeneous degree of the broken solution reservoir are serious, the longitudinal fracture is deep and large, and the lateral fracture is locally communicated. The well group collaborative water control method firstly recognizes and identifies a bottom water source well in a reservoir unit through geological data and the like, namely, the invention further comprehensively considers the dynamic and static response of the well group, the sequential water-meeting characteristic, the reserve characteristic, the position distribution and the stratum profile characteristic of the well group, namely, the connectivity among the well groups, the dynamic and static correspondence among the well groups, poor water flooding effect and imperfect well pattern on the basis of the geological data; the well group has the characteristic of water breakthrough in sequence, bottom water is lifted, shan Jingshui is flooded, water in adjacent wells rises, and water channeling phenomenon exists; reserve volume: the well group area has good reserves and high accumulated oil production, but the energy is not excessively large; position distribution: near the source, a longitudinal low-position well, a planar water-inflow upstream well; geology: the device penetrates through deep fracture in the longitudinal direction, effectively communicates oil sources or water sources, is low in well control degree due to fracture separation influence, is rich in residual oil, and realizes integral water control of a reservoir unit by means of water shutoff measures which are implemented in a coordinated and targeted mode through linkage of three types of oil wells and other planes in a control unit are communicated with the water-containing rising speed of the oil wells. The problem of current single well water shutoff technique and water injection profile control are applied to the poor adaptability of disconnected solution oil reservoir is effectively solved, by "single-point scattered shutoff" to "unit overall control" the transformation, according to the water outlet route, from low to high shutoff step by step, realized the scale water control.
Specifically, as shown in a schematic diagram in fig. 1, the method performs well group collaborative water control after well group identification, performs high-strength blocking c on a bottom water source well, performs medium-strength blocking b on a middle water channeling well, performs low-strength blocking a on a top water seeing well, preferably performs high-strength blocking c on the bottom water source well by adopting a rubber particle blocking agent and a high-temperature-resistant gel blocking agent in the well group collaborative water control step, performs medium-strength blocking b on the middle water channeling well by adopting a delayed expansion particle blocking agent, a mineral powder gel blocking agent and a high-temperature gel blocking agent, and performs low-strength blocking a on a top water seeing well by adopting an oil-soluble adhesion particle blocking agent, a selective temperature-resistant gel blocking agent and a high-temperature gel blocking agent.
Preferably, in the well group collaborative water control step, the identified oil wells of various types can be divided into a front slug, a main slug and a sealing slug, corresponding plugging agents are injected into the front slug, the main slug and the sealing slug, and the components or proportions of the plugging agents injected into the corresponding slugs of the oil wells of various types are different from each other. That is, aiming at three types of oil wells of low, medium and high, corresponding medicament systems are designated to control water by matching with a water shutoff construction process.
① . The bottom water source well, which can be called as a low-strength plugging well, adopts a system of a preposed rubber particle plugging agent, a main body high-temperature-resistant gel plugging agent and a high-strength solidification sealing agent, and is divided into three slugs to inject the corresponding plugging agent into an oil well so as to realize high-strength plugging.
In the front section plug of the bottom water source well, 1.0-2.0% of rubber particles are added into water according to the mass percentage concentration to prepare a plugging agent, after the plugging agent is prepared, the plugging agent is injected into a stratum, the injection amount is 800-1000, the density of the rubber particles is 1.16-1.19g/cm 3, the particle size range is less than 10mm, the rubber particles can keep stable performance for a long time without obvious change under the environment of 130 ℃, and the rubber particles have elasticity.
In the main body slug of the bottom water source well, a high-temperature-resistant gel plugging agent with the density of 1.07-1.09/cm 3 and the viscosity of 30-35mpa.s is prepared, and is injected into a stratum after the preparation, the injection amount is 200-300 square, the high-temperature-resistant gel plugging agent is based on the existing domestic auxiliary agent system, a monomer or a polymer with the temperature resistance and salt resistance is used by molecular design, or a crosslinking agent with a ring structure can be introduced into a plugging agent molecular chain, or a naphthol/urotropine (aldehyde) crosslinking agent is used for replacing a metal crosslinking agent, the whole gel system formula is subjected to serial reconstruction, so that a small-molecular low-viscosity, shearing-resistant and low-damage selective plugging agent system is formed, the temperature resistance and salt resistance of the plugging agent are improved, the gel forming time is prolonged, the gel forming time is dynamically not formed after the gel is modified, and the requirement of 8-10h adjustable property of the gel forming time under the static 140 ℃ is met.
In the sealing section plug of the bottom water source well, 2-5% of ammonium chloride, 5-10% of G-level cement and 0.01-1% of retarder (such as borate or silicate) are added into water according to the mass percentage concentration, and after the retarder is prepared, the retarder is injected into stratum, wherein the injection amount is 5-10.
Further preferably, after the three slugs are injected with the corresponding plugging agents, a displacement slug is further arranged, firstly, 10 parts of guanidine gum solution with the mass percent concentration of 0.2% are added into water, and then the displacement fluid is injected to displace the plugging agents to the deep part of the stratum. The displacement fluid is oil field water, and the dosage is 1.5-2.0 times of the sum of the volume of the ground manifold, the volume of the construction string (or annular space) and the volume of the completion casing from the construction string to the artificial lower well.
② . The middle water channeling well, also called as a middle strong blocking well, adopts a prepositive delayed expansion particle blocking agent, a main mineral powder gel blocking agent and a high-temperature gel blocking agent sealing agent system, and is divided into three slugs to inject corresponding blocking agents into an oil well so as to realize medium-strength blocking.
In the front section plug of the middle water channeling well, 1.0-2.0% of delayed expansion particles are added into water according to the mass percentage concentration to prepare a plugging agent, after the plugging agent is prepared, the plugging agent is injected into a stratum, the injection amount is 100-200 square, the delayed expansion particles are developed aiming at a large crack channel of the middle water channeling well of a broken solution reservoir, the swelling is improved by mixing rubber and additives, the consumption of hydrophilic agent is increased in a rubber matrix, a calcium-magnesium ion chelating agent is added to delay the swelling, the hydrophilicity is reduced, meanwhile, grafting crosslinking is carried out, a chemical crosslinking network is constructed to prevent retraction of the plugging agent, uniform particles with the thickness of 1-1.5mm are formed, and the plugging agent can slowly expand to 2-3 times of the original volume when meeting water and is kept stable for a long time, so that larger stratum cracks of the middle water channeling well are plugged.
In the main body slug of the middle water channeling well, a mineral powder gel plugging agent with the density of 1.15-1.18/cm 3 and the viscosity of 30-35mpa.s is prepared, and after the mineral powder gel plugging agent is prepared, the mineral powder gel plugging agent is injected into a stratum, the injection amount is 300-500 square, and the mineral powder gel plugging agent has the characteristics of compressive strength of more than 0.1MPa, dynamic non-thickening in 8 hours, low cost, capability of being injected in a large amount, and capability of being matched with the delayed expansion particles to effectively plug large cracks.
In the sealing section plug of the middle water channeling well, a high-temperature gel plugging agent with the density of 1.07-1.09/cm < 3 > and the viscosity of 30-35mpa.s is prepared, and is of the same type as the high-temperature plugging agent, and is injected into a stratum after being prepared, wherein the injection amount is 50-80 square.
Further preferably, after the three slugs are injected with the corresponding plugging agents, a displacement slug is further arranged, firstly, 10 parts of guanidine gum solution with the mass percent concentration of 0.2% are added into water, and then the displacement fluid is injected to displace the plugging agents to the deep part of the stratum. The displacement fluid is oil field water, and the dosage is 1.0-1.5 times of the sum of the volume of the ground manifold, the volume of the construction string (or annular space) and the volume of the completion casing from the construction string to the artificial lower well.
③ . The top water is water-breakthrough, also called high-part weakly-regulated plugging well, adopts a system of prepositive oil-soluble adhesion particle plugging agent, main body selective gel plugging agent and high-temperature gel plugging agent sealing agent, and is divided into three slugs to inject the corresponding plugging agent into an oil well, so as to realize low-strength plugging.
In the front slug of the top water-seeing well, 3.0-5.0% of oil-soluble adhesion particles are added into water according to the mass percentage concentration to prepare a plugging agent, after the plugging agent is prepared, the plugging agent is injected into a stratum, the injection amount is 100-300 square, the oil-soluble adhesion particles are researched and developed through basic resin particles, and auxiliaries such as strength regulator, density regulator and the like are added to form the plugging agent, and the plugging agent is adhered with water particles under the conditions of 150 ℃ and 21 ten thousand mineralization and has certain thermoplastic and bearing strength, so that reverse blocking is realized and the strength is adjustable.
In the main body slug of the top water-seeing well, the selective temperature-resistant gel plugging agent with the density of 1.12-1.14/cm 3 is prepared by adopting stratum water, after the preparation, the gel is injected into the stratum, the injection quantity is 50-200 square, the problem of low temperature resistance of the conventional gel is improved, the gel can meet the requirement of forming gel at 130 ℃ for 3-5 hours, no-flow gel is formed, the surface of the inverted gel is slightly deformed, and the salt tolerance is more than 21 ten thousand mineralizations.
In the sealing section plug of the top water-seeing well, a high-temperature gel plugging agent with the density of 1.07-1.09/cm 3 and the viscosity of 30-35mpa.s is prepared, and is of the same type as the high-temperature plugging agent, and is injected into a stratum after being prepared, wherein the injection amount is 50-80 square.
Further preferably, after the corresponding plugging agent is injected into the three slugs, a displacement slug is further arranged, wherein 0.2% of guanidine gum solution is added into water according to the mass percent concentration for 10 times, then the displacement fluid is injected to displace the plugging agent to the deep part of the stratum, and the displacement fluid is oil field water, and the dosage of the displacement fluid is 1.0 times of the sum of the volume of a ground manifold, the volume of a construction string (or an annular space) and the volume of a completion casing from the construction string to an artificial bottom.
It should be noted that the above-described embodiments will enable those skilled in the art to more fully understand the invention, but do not limit it in any way. Therefore, although the present invention has been described in detail with reference to the drawings and examples, it will be understood by those skilled in the art that the present invention may be modified or equivalent, and in all cases, all technical solutions and modifications which do not depart from the spirit and scope of the present invention are intended to be included in the scope of the present invention.
Claims (9)
1. The well group cooperative water control method for the disconnected solution oil reservoir is characterized by comprising the following steps of:
A well group identification step, namely carrying out oil well type identification according to geological data, dynamic and static response of the well group and water breakthrough characteristics of the well group in sequence, identifying a well which is communicated with a water source in the longitudinal direction and is displayed by a deep bead string as a bottom water source well, identifying a well which is communicated with the water source well by a part of crack channels and is characterized by water breakthrough and high water content in middle part as a middle water channeling well, and identifying a well which is far away from the bottom water source well and is positioned high in the well region as a top water finding well;
A well group collaborative water control step, namely injecting a high-strength plugging well plugging agent into the bottom water source well to perform high-strength plugging, plugging a main rising channel of bottom water, and delaying flooding of a near water source well; injecting a medium-strength plugging agent into the middle water channeling well to perform medium-strength plugging, so as to plug a large crack channel and inhibit water channeling; injecting a weak plugging agent for regulating and plugging the top water-looking well according to the water channeling degree of the top water-looking well so as to regulate and plug at low strength and selectively plug a water channeling channel; specifically, the high-strength plugging agent is used for plugging by adopting a rubber particle plugging agent and a high-temperature-resistant gel plugging agent; the medium-strength plugging agent is plugging by adopting delayed expansion particle plugging agent, mineral powder gel plugging agent and high-temperature gel plugging agent; the weakly plugging agent adopts oil-soluble adhesion particle plugging agent, selective temperature-resistant gel plugging agent and high-temperature gel plugging agent for plugging.
2. The well group collaborative water control method for a solution-breaking oil reservoir according to claim 1, wherein in the well group identification step, oil well type identification is performed according to geological data, well group dynamic-static response and well group sequential water-meeting characteristics, and also by combining reserve characteristics, position distribution and stratum profile characteristics.
3. The well group collaborative water control method for a solution-breaking oil reservoir according to claim 1, wherein in the well group collaborative water control step, each type of oil well identified is evenly divided into three slugs, and corresponding plugging agents are injected into the three slugs, wherein the three slugs comprise a front slug, a main slug and a sealing slug, and the components or proportions of the plugging agents injected into the corresponding slugs of each type of oil well are different from each other.
4. A well group collaborative water control method for a solution reservoir according to claim 3, wherein the components of the corresponding slugs of each type of well injected with plugging agent are respectively:
bottom water source well:
The pre-slug is prepared by adding 1.0% -2.0% of rubber particles into water according to the mass percentage concentration, and then injecting the prepared plugging agent into a stratum with the injection amount of 800-1000 square; the main body slug is prepared into a high-temperature-resistant gel plugging agent with the density of 1.07-1.09/cm 3 and the viscosity of 30-35mpa.s, and the high-temperature-resistant gel plugging agent is injected into a stratum after being prepared, wherein the injection amount is 200-300 square; the sealing slug is prepared by adding 2-5% of ammonium chloride, 5-10% of G-level cement and 0.01-1% of retarder into water according to the mass percentage concentration, and injecting the mixture into a stratum with the injection amount of 5-10;
Middle water channeling well:
The pre-slug is prepared by adding 1.0-2.0% of delayed expansion particles into water according to the mass percentage concentration, and then injecting the prepared plugging agent into a stratum, wherein the injection amount is 100-200 square; preparing a main body slug, namely preparing a mineral powder gel plugging agent with the density of 1.15-1.18/cm 3 and the viscosity of 30-35mpa.s, and injecting the mineral powder gel plugging agent into a stratum after the mineral powder gel plugging agent is prepared, wherein the injection amount is 300-500 square; sealing the slug, preparing a high-temperature gel plugging agent with the density of 1.07-1.09/cm 3 and the viscosity of 30-35mpa.s, and injecting the high-temperature gel plugging agent into a stratum after the high-temperature gel plugging agent is prepared, wherein the injection amount is 50-80 square;
top water well:
the pre-slug is prepared by adding 3.0-5.0% of oil-soluble adhesion particles into water according to the mass percentage concentration, and then injecting the prepared plugging agent into a stratum with the injection amount of 100-300 square; the main body slug is prepared into a selective temperature-resistant gel plugging agent with the density of 1.12-1.14/cm 3, and the plugging agent is injected into a stratum after being prepared, wherein the injection amount is 50-200 square; sealing the slug, preparing high-temperature gel plugging agent with density of 1.07-1.09/cm 3 and viscosity of 30-35mpa.s, and injecting into stratum after preparing, wherein the injection amount is 50-80 square.
5. The method for collaborative water control of a well group for a dissolved-out reservoir according to claim 4, wherein the bottom-water-source well front-end slugs employ rubber particles with a particle density of 1.16-1.19g/cm 3, a particle size range of <10mm, and a stable performance and elasticity at 130 ℃ environment;
and/or the high-temperature-resistant gel plugging agent adopted by the bottom water source well main body slug is a monomer or a polymer with temperature resistance and salt resistance, or a cross-linking agent which leads the molecular chain of the plugging agent to be introduced into a ring structure, or a naphthol/urotropine cross-linking agent, is dynamically not glued, and has the glue-forming time of 8-10 hours at 140 ℃ under static state;
and/or mixing the delayed expansion particles adopted by the front section plug of the middle water channeling well with rubber and an additive to form a rubber matrix, adding the dosage of a hydrophilic agent and a calcium-magnesium ion chelating agent into the rubber matrix, constructing a chemical crosslinking network, forming uniform particles with the size of 1-1.5mm, and slowly expanding to 2-3 times of the original volume when meeting water and keeping stable;
and/or the mineral powder gel plugging agent adopted by the main body slug of the middle water channeling well has the characteristics of compressive strength of more than 0.1MPa and dynamic non-thickening for a plurality of hours;
And/or, the oil-soluble adhesion particles adopted by the top water-seeing well front-end slug are formed by adding strength regulator and density regulator serving as auxiliary agents on the basis of resin particles, and the top water-seeing well front-end slug is adhered by water particles under the conditions of 150 ℃ and 21 thousands of mineralization and has specific thermoplasticity and bearing strength;
And/or the selective temperature-resistant gel plugging agent adopted by the top water-meeting well main body slug meets the requirement of forming gel for 3-5 hours at 130 ℃ and forming non-flowing gel, the surface of the inverted gel is slightly deformed, and the salt tolerance is more than 21 ten thousand mineralizations.
6. The method of collaborative water control of a well group for a solution-breaking reservoir according to claim 4, wherein retarder employed in the bottom-water well seal slugs is borate or silicate.
7. The method for collaborative water control of a well group for a dissolved-out reservoir according to claim 4, wherein the gel plugging agent used in each type of well body slugs comprises a polysilicomer, an activator, a retarder and a bentonite filler as main components.
8. The well group collaborative water control method for a solution-breaking oil reservoir according to claim 4, wherein after three slugs of each oil well are injected with corresponding plugging agents, the method further comprises displacing slugs, wherein the displacing slugs are added with 10 parts of guanidine gum solution with the concentration of 0.2% by mass, and the displacing fluid is injected to displace the plugging agents to the deep part of the stratum.
9. The method of claim 8, wherein the displacement fluid is oilfield water, and the bottom water source well, the middle water channeling well and the top water seeing well are used in an amount of 1.5-2.0 times, 1.0-1.5 times and 1.0 times the sum of the surface manifold volume and the construction string volume and the completion casing volume from the construction string to the artificial lower well, respectively.
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