CN102199418A - Inorganic solidifying system for controlling bottom water coning in fracture-cavity karst reservoir, and injection method thereof - Google Patents
Inorganic solidifying system for controlling bottom water coning in fracture-cavity karst reservoir, and injection method thereof Download PDFInfo
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- CN102199418A CN102199418A CN2011100678726A CN201110067872A CN102199418A CN 102199418 A CN102199418 A CN 102199418A CN 2011100678726 A CN2011100678726 A CN 2011100678726A CN 201110067872 A CN201110067872 A CN 201110067872A CN 102199418 A CN102199418 A CN 102199418A
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Abstract
The invention provides an inorganic solidifying system for controlling bottom water coning in a fracture-cavity karst reservoir, and an injection method of the inorganic solidifying system. The inorganic solidifying system comprises ultrafine cement, a density modifying agent, a reinforcing agent, a suspension dispersing agent, a frame bridging agent, a drag reducer, and a retarder. The density of the inorganic solidifying system is 1.06 to 1.09 g/m<3>. The initial setting time of the system under a temperature of 130 DEG C is 5 to 10 hours. The compressive strength of the system is 1.0 to 4.0 Mpa. The injection method is that: first, an inorganic solidification system with a relatively large density is prepared and is injected into a stratum, then an inorganic solidifying system with a relatively small density is prepared and is injected into the stratum, and finally a displacing liquid is injected into the stratum. Because the density of the inorganic solidifying system is between the density of oil in the oil reservoir and the density of salt water in the stratum, the inorganic solidifying system is positioned below the oil reservoir and above the salt water reservoir in the stratum. Therefore, the inorganic solidifying system can be solidified to form a separator near the separating surface between oil and water. Thus, the winding direction of the bottom water is efficiently changed, the bottom water coning is controlled, the oil flooding efficiency of the bottom water is improved, and the fracture-cavity karst reservoir exploitation effect is improved.
Description
Technical field:
The present invention relates to a kind of oilfield chemistry with agent and method for implanting thereof, especially stitch chemical system and the method for implanting thereof that hole type Carbonate Reservoir is controlled bottom water coning at high temperature and high salt.
Background technology:
Type bottom water reservoir most of development scheme of horizontal well that adopts in present many seams hole suppresses bottom water coning.But because oil recovery rate is too fast, perhaps the development time longer, cause the energy shortage on stratum, cause that end water advances to the shooting of oil well position, forms bottom water coning.When bottom-water breakthrough, the water ratio of oil well rises, and end water is from high seepage well section output and suppress low seepage well section production fluid, and then causes a large amount of remaining oil enrichments to be difficult to extraction at hypotonic section.
The method of general control bottom water coning is to set up end water dividing plate near water-oil interface, basic skills is with the intensive perforation in the interval of 0.5m～2.0m on water-oil interface, with pkr the oil jacket annular space is separated, clamp-on dividing plate liquid system (as gel, frozen glue, solid phase particles, gas etc.) by oil pipe to intensive perforation interval, can set up the dividing plate of 3～5m, bottom water coning is had control action kou preferably.But for high temperature and high salt seam hole type Carbonate Reservoir, choose suitable dividing plate liquid and find perforation interval accurately, sit accurate pkr sizable difficulty is just arranged, therefore, set up the method and the dividing plate liquid of end water dividing plate and be difficult to adaptation with the conventional perforation that passes through.
So at high temperature and high salt seam hole bottom water reservoir characteristics, provide the inorganic solidified system of a kind of extremely-low density can not only satisfy the requirement of high temperature and high salt, simultaneously can adjust autologous density, utilize gravitational differentiation on water-oil interface, to form effective shutoff, and then improve end ripples and volume, improve oil recovery factor.
Summary of the invention:
The objective of the invention is to provide a kind of inorganic solidified system and method for implanting thereof that stitches hole type Carbonate Reservoir control bottom water coning, utilize injection chemical agent and local water, oil density difference to produce gravitational differentiation, on water-oil interface, set up the dividing plate of control bottom water coning, effectively change end water and stream direction, thereby control bottom water coning, improve bottom aquifer drive oil efficient, improve the development effectiveness of seam hole type bottom water reservoir.
Purpose of the present invention realizes by following scheme: the inorganic solidified system of said seam hole type Carbonate Reservoir control bottom water coning is made up of superfine cement, density adjustment agent, toughener, suspension dispersive agent, skeleton bridging agent, flow improver and retardant, and wherein the particle diameter of superfine cement is that 10～100 μ m, density are 2.8～3.2g/cm
3, the functional quality mark is 24%～27%; It is hollow glass micro-ball that density is adjusted agent, and its particle diameter is 20～200 μ m, and density is 0.6～0.8g/cm
3, the functional quality mark is 17%～20%; Toughener is a white rouge, and its density is about 2.6～2.8g/cm
3, particle diameter is 0.15～0.20 μ m, the functional quality mark is 1%～4%; Suspension dispersive agent is from high molecular polymers such as polyacrylamides, and the functional quality mark is 0.2%～0.6%; The skeleton bridging agent is a carbon fiber, and its length is that 0.05～0.10mm, density are 1.45～1.55g/cm
3, the functional quality mark is 0～0.3%; Flow improver is that the functional quality mark is 0.1～0.6% from one or more of hydroxycarboxylate, vinyl monomer oligopolymer and sulfonation aldoketones polycondensate; Retardant is that the functional quality mark is 0～0.2% from one or more of borate, phosphonate, carboxylate salt and sulfonated lignin; All the other are water, more than each constituent mass mark sum be 100%.The inorganic solidified system density of being made up of said components is 1.06～1.10g/cm
3, the presetting period under 130 ℃ is 5～10h, ultimate compression strength is 1.0～4.0MPa.
The method for implanting of the inorganic solidified system of forming according to said components is that at first to prepare and inject density be 1.08g/cm
3～1.10g/cm
3Inorganic solidified system, injection rate is per 1 meter thickness oil reservoir 6～10m
3, preparing then and injecting density is 1.06g/cm
3～1.08g/cm
3Inorganic solidified system, injection rate is per 1 meter thickness oil reservoir 3～5m
3, last implantation quality mark be 0.4%～06% the HPAM aqueous solution as crossing displacing liquid, injection rate is per 1 meter thickness oil reservoir 1～3m
3Above-mentioned system is made into the aqueous solution respectively, filters by screen filter and injects corresponding well successively by the profile control pump.Injection speed is 2～4m
3H
-1, injection pressure is no more than 80% of formation-parting pressure, and injection pressure is no more than 5.0MPa with the difference that initially enters reservoir pressure.
The invention has the beneficial effects as follows: because formation water salinity reaches 20 * 10
4Mg/L, density is 1.14g/cm
3, and underground oil density is 0.85g/cm
3, the inorganic solidified system density of injection is 1.06～1.10g/cm
3, be between underground oil density and the stratum high-salinity brine density, so it will be positioned under the oil reservoir, on the high-salinity brine layer, therefore inorganic solidified System solidifying forms dividing plate near water-oil interface, and effectively change end water and stream direction, and then the control bottom water coning.
Embodiment:
Further specify the present invention below in conjunction with embodiment.
Embodiment 1: the consisting of of inorganic solidified system: (particle diameter is that 10～100 μ m, density are 2.8～3.2g/cm to superfine cement 25.46%
3), density is adjusted agent 19.94%, toughener 2.97%, and suspension dispersive agent 0.51%, flow improver 0.38%, retardant 0.13%, skeleton bridging agent 0.21%, all the other are water, and each component sum is 100%, and stirring and forming density is 1.061g/cm
3System, down the presetting period of these systems is 5.5h, ultimate compression strength 1.5MPa at 130 ℃.
Embodiment 2: the consisting of of inorganic solidified system: (particle diameter is that 10～100 μ m, density are 2.8～3.2g/cm to superfine cement 26.47%
3), density is adjusted agent 17.64%, toughener 2.21%, and suspension dispersive agent 0.53%, flow improver 0.40%, retardant 0.13%, skeleton bridging agent 0.22%, all the other are water, and each component sum is 100%, and stirring and forming density is 1.078g/cm
3System, down the presetting period of these systems is 7.0h, ultimate compression strength 2.2MPa at 130 ℃.
Embodiment 3: the consisting of of inorganic solidified system: (particle diameter is that 10～100 μ m, density are 2.8～3.2g/cm to superfine cement 27.81%
3), density is adjusted agent 17.12%, toughener 3.00%, and suspension dispersive agent 0.51%, flow improver 0.39%, retardant 0.13%, skeleton bridging agent 0.21%, all the other are water, and each component sum is 100%, and stirring and forming density is 1.100g/cm
3System, down the presetting period of these systems is 6.0h, ultimate compression strength 3.0MPa at 130 ℃.
The rig-site utilization situation:
Existing A test pit, its basic condition sees Table 1, and the working fluid situation sees Table 2.
Table 1 test pit basic condition
| Situation | The A well |
| Commissioning date | In April, 1999 |
| The producing horizon position | 02yj；C1k |
| Oil reservoir well section/(m) | 5250～5540 |
| Perforated interval/(m) | 5260～5540 |
| The oil reservoir type | Seam hole type carbonatite |
| Formation temperature/(℃) | 130 |
Table 2 A test pit working fluid applicable cases (130 ℃)
Test-results shows that water ratio average out to 99.2% before the A well construction is up to 99.9%, and the construction back is minimum to be 88.0%, and is stabilized in about 91.6%, and oil offtake is by the preceding average 31.1td of construction
-1Be increased to 37.0td
-1, being valid up to 10 months, production gain reaches 1753.3t, and effect is obvious.
Claims (2)
1. one kind is stitched the inorganic solidified system that hole type Carbonate Reservoir is controlled bottom water coning, it is characterized in that, adjust agent, toughener, suspension dispersive agent, skeleton bridging agent, flow improver and retardant by superfine cement, density and form, wherein the particle diameter of superfine cement is that 10～100 μ m, density are 2.8～3.2g/cm
3, the functional quality mark is 24%～26%; It is hollow glass micro-ball that density is adjusted agent, and its particle diameter is that 20～200 μ m, density are 0.6～0.8g/cm
3, the functional quality mark is 17%～19%; Toughener is a white rouge, and its density is 2.6～2.8g/cm
3, particle diameter is 0.15～0.20 μ m, the functional quality mark is 1%～3%; Suspension dispersive agent is high molecular polymer (as polyacrylamide etc.), and the functional quality mark is 0.2%～0.5%; The skeleton bridging agent is a carbon fiber, and its length is 0.05～0.10mm, and density is 1.45～1.55g/cm
3, the functional quality mark is 0～0.2%; Flow improver is that the functional quality mark is 0.1～0.3% from one or more of hydroxycarboxylate, vinyl monomer oligopolymer and sulfonation aldoketones polycondensate; Retardant is that the functional quality mark is 0～0.2% from one or more of borate, phosphonate, carboxylate salt and sulfonated lignin; All the other are water; More than each constituent mass mark sum be 100%.
2. control the method for implanting of the inorganic solidified system of bottom water coning according to the described seam of claim 1 hole type Carbonate Reservoir, it is characterized in that: at first inject the relatively large inorganic solidified system of density, inject the less relatively inorganic solidified system of density then, injected displacing liquid at last, concrete steps are as follows:
1. preparing and injecting density density is 1.08g/cm
3～1.10g/cm
3Inorganic solidified system, injection rate is per 1 meter thickness oil reservoir 6～10m
3
2. preparing and injecting density is 1.06g/cm
3～1.08g/cm
3Inorganic solidified system, injection rate is per 1 meter thickness oil reservoir 3～5m
3
3. the implantation quality mark be 0.4%～0.6% the HPAM aqueous solution as crossing displacing liquid, injection rate is per 1 meter thickness oil reservoir 1～3m
3
The injection speed of above-mentioned system is 2～4m
3H
-1, injection pressure is no more than 80% of formation-parting pressure, and injection pressure is no more than 5.0MPa with the difference that initially enters reservoir pressure.
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|---|---|---|---|
| CN 201110067872 CN102199418B (en) | 2011-03-11 | 2011-03-11 | Inorganic solidifying system for controlling bottom water coning in fracture-cavity karst reservoir, and injection method thereof |
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|---|---|---|---|
| CN 201110067872 CN102199418B (en) | 2011-03-11 | 2011-03-11 | Inorganic solidifying system for controlling bottom water coning in fracture-cavity karst reservoir, and injection method thereof |
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Cited By (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102587858A (en) * | 2012-03-09 | 2012-07-18 | 中国石油化工股份有限公司 | Method for blocking water for fracture and hole type reservoir |
| CN107057671A (en) * | 2017-05-26 | 2017-08-18 | 山东大学 | A kind of water-in-oil emulsion interface packing system, its preparation method and water-oil separating technique and application with self-reparing capability |
| CN107474807A (en) * | 2017-08-25 | 2017-12-15 | 中国石油化工股份有限公司 | Fracture-pore reservoir runner regulator and preparation method thereof |
| CN108643881A (en) * | 2018-04-27 | 2018-10-12 | 中国石油大学(华东) | A kind of control bottom water rising chemical clapboard and the preparation method and application thereof |
| CN111852394A (en) * | 2020-07-23 | 2020-10-30 | 西安诚科石油工程技术服务有限公司 | Method for blocking bottom water coning |
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| CN103361041B (en) * | 2013-08-09 | 2015-10-21 | 卫辉市化工有限公司 | A kind of preparation method of high-density gas channeling prevention well cementing grout |
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| Publication number | Priority date | Publication date | Assignee | Title |
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| CN102587858A (en) * | 2012-03-09 | 2012-07-18 | 中国石油化工股份有限公司 | Method for blocking water for fracture and hole type reservoir |
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| CN107057671A (en) * | 2017-05-26 | 2017-08-18 | 山东大学 | A kind of water-in-oil emulsion interface packing system, its preparation method and water-oil separating technique and application with self-reparing capability |
| CN107474807A (en) * | 2017-08-25 | 2017-12-15 | 中国石油化工股份有限公司 | Fracture-pore reservoir runner regulator and preparation method thereof |
| CN108643881A (en) * | 2018-04-27 | 2018-10-12 | 中国石油大学(华东) | A kind of control bottom water rising chemical clapboard and the preparation method and application thereof |
| CN108643881B (en) * | 2018-04-27 | 2020-04-14 | 中国石油大学(华东) | Chemical partition plate for controlling bottom water to rise and preparation method and application thereof |
| CN111852394A (en) * | 2020-07-23 | 2020-10-30 | 西安诚科石油工程技术服务有限公司 | Method for blocking bottom water coning |
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