CN114427376A - Lateral drive synergistic method between large-bottom water oil reservoir wells - Google Patents
Lateral drive synergistic method between large-bottom water oil reservoir wells Download PDFInfo
- Publication number
- CN114427376A CN114427376A CN202011002770.1A CN202011002770A CN114427376A CN 114427376 A CN114427376 A CN 114427376A CN 202011002770 A CN202011002770 A CN 202011002770A CN 114427376 A CN114427376 A CN 114427376A
- Authority
- CN
- China
- Prior art keywords
- oil
- displacement
- slug
- water
- viscous liquid
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 92
- 238000000034 method Methods 0.000 title claims abstract description 25
- 230000002195 synergetic effect Effects 0.000 title description 3
- 238000006073 displacement reaction Methods 0.000 claims abstract description 70
- 238000002347 injection Methods 0.000 claims abstract description 58
- 239000007924 injection Substances 0.000 claims abstract description 58
- 238000005192 partition Methods 0.000 claims abstract description 29
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 19
- 239000003129 oil well Substances 0.000 claims abstract description 18
- 241000237858 Gastropoda Species 0.000 claims abstract description 16
- 238000004519 manufacturing process Methods 0.000 claims abstract description 12
- 238000005516 engineering process Methods 0.000 claims abstract description 11
- 239000011148 porous material Substances 0.000 claims abstract description 9
- 238000010276 construction Methods 0.000 claims abstract description 8
- 230000035699 permeability Effects 0.000 claims abstract description 5
- 239000003921 oil Substances 0.000 claims description 62
- 239000007788 liquid Substances 0.000 claims description 45
- 229920000642 polymer Polymers 0.000 claims description 32
- 239000008398 formation water Substances 0.000 claims description 20
- 239000012752 auxiliary agent Substances 0.000 claims description 9
- 239000003431 cross linking reagent Substances 0.000 claims description 7
- 239000010779 crude oil Substances 0.000 claims description 7
- 150000003839 salts Chemical class 0.000 claims description 5
- 230000002708 enhancing effect Effects 0.000 claims description 4
- 238000009472 formulation Methods 0.000 claims description 4
- 239000000203 mixture Substances 0.000 claims description 4
- 230000000903 blocking effect Effects 0.000 claims description 3
- 230000005465 channeling Effects 0.000 claims description 3
- 238000007789 sealing Methods 0.000 claims description 3
- 230000007480 spreading Effects 0.000 claims description 3
- 238000003892 spreading Methods 0.000 claims description 3
- 239000012530 fluid Substances 0.000 claims 1
- 238000011084 recovery Methods 0.000 abstract description 6
- 210000003097 mucus Anatomy 0.000 description 12
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 4
- 238000011161 development Methods 0.000 description 4
- 229920001807 Urea-formaldehyde Polymers 0.000 description 2
- GZCGUPFRVQAUEE-SLPGGIOYSA-N aldehydo-D-glucose Chemical compound OC[C@@H](O)[C@@H](O)[C@H](O)[C@@H](O)C=O GZCGUPFRVQAUEE-SLPGGIOYSA-N 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 229910052757 nitrogen Inorganic materials 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- 239000011435 rock Substances 0.000 description 2
- 239000004576 sand Substances 0.000 description 2
- 238000003756 stirring Methods 0.000 description 2
- 239000002671 adjuvant Substances 0.000 description 1
- 238000009412 basement excavation Methods 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- ZFXVRMSLJDYJCH-UHFFFAOYSA-N calcium magnesium Chemical compound [Mg].[Ca] ZFXVRMSLJDYJCH-UHFFFAOYSA-N 0.000 description 1
- 239000003814 drug Substances 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 239000006260 foam Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 238000001556 precipitation Methods 0.000 description 1
- 230000002265 prevention Effects 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 235000020681 well water Nutrition 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
- C09K8/426—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells for plugging
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/588—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
Abstract
The invention provides a method for lateral drive synergism between large-bottom water oil reservoirs, which comprises the following steps: s1, establishing a three-dimensional bottom water oil reservoir physical model device according to the relative thickness of a stratum and an oil layer where an oil well to be displaced is located, the inter-well distance and the relative size of bottom water parameters, and calculating the using amount of a plugging agent; s2, designing a partition plate slug, a displacement slug and a displacement slug three-section water plugging slug, and calculating the total injection amount according to the pore volume of the oil reservoir; s3, respectively calculating the injection pressure value and the injection displacement of the three-section water plugging slug according to the production pressure gradient, the injection-production ratio and the stratum permeability by combining the plugging agent dosage calculated in the step S1 and the total injection amount calculated according to the oil reservoir pore volume in the step S2; and S4, injecting three sections of water plugging slugs into the stratum of the oil well to be displaced in sequence according to the calculated injection displacement to perform displacement construction. According to the invention, by combining the preposed partition plate and the lateral displacement technology, the residual oil between wells is efficiently displaced, the residual oil between wells is improved, and the later recovery rate is greatly improved.
Description
Technical Field
The invention relates to the technical field of petroleum development, in particular to a method for lateral drive synergism between large-bottom water oil reservoirs.
Background
The tower river clastic rock oil reservoir has the characteristics of 'one-ultra three-high': ultra-deep (burying depth 4200-5100 m), high temperature (90-137 ℃), high salinity (total salinity of formation water 21 x 10)4mg/L, calcium magnesium particle content 1.2 x 104mg/L) and high water-oil system ratio (more than 500). Along with the oil reservoir development, due to strong reservoir heterogeneity, the water in the oil well is seriously flooded due to the fact that water in the bottom water oil reservoir of the clastic rocks of the Tahe oil field is coning in the process of the oil reservoir development, and the remaining oil is mainly distributed in the low-permeability section around the well, the high part of the reservoir and the space between the wells to form a control area. In the early stage, the bottom water is controlled mainly in an oil well water plugging mode, the potential of residual oil around the excavated well is excavated, but after multiple rounds of water plugging, the water plugging effect is rapidly reduced. The later recovery direction gradually turns to the residual oil between wells and at the top for potential excavation, but the conventional three-extraction technology cannot be applied due to the harsh oil reservoir conditions.
For example, a paper (research on artificial partition water plugging technology for bottom water reservoirs in the nine — 4 area, southwest petroleum university [ D ], 2016) proposes an artificial partition water plugging technology for a urea-formaldehyde resin plugging agent system suitable for the reservoirs by combining geological characteristics and development current situations of the reservoirs. The artificial partition plate water plugging technology is an effective method for controlling bottom water coning by chemical water plugging, can prevent bottom water from coning to an oil well, changes the seepage direction of the bottom water around a shaft and achieves the effects of precipitation and oil increment. The urea-formaldehyde resin plugging agent system has the characteristics of low initial viscosity, good injectability and high plugging strength after curing, has the functions of sand prevention and sand fixation, and has certain applicability to target oil reservoirs. An artificial partition plate plugging agent system suitable for the nine 4-zone bottom water reservoir is optimized through experiments, and the performance of the plugging agent system is evaluated.
Just like the technologies disclosed in the above-mentioned papers, most of the prior arts are single well residual oil potential at the early stage, and residual oil potential around the excavated well is excavated, and no effective treatment means is provided at present for the residual oil enrichment between bottom water reservoir wells during the later-stage recovery.
Disclosure of Invention
In order to solve the problem that the enrichment of residual oil between wells of a bottom water reservoir recovered in the later period in the prior art lacks an effective treatment means, the invention provides a method for enhancing the efficiency of lateral displacement between wells of a large bottom water reservoir.
The technical scheme of the invention is as follows:
a method for lateral drive synergism between large-bottom water oil reservoirs is characterized by comprising the following steps:
s1, establishing a three-dimensional bottom water oil reservoir physical model device according to the relative thickness of a stratum and an oil layer where an oil well to be displaced is located, the inter-well distance and the relative size of bottom water parameters, and calculating the using amount of a plugging agent;
s2, designing a partition plate slug, a displacement slug and a displacement slug three-section water plugging slug, and calculating the total injection amount according to the pore volume of the oil reservoir; the partition plate slug adopts a first-strength micro-viscous liquid system, the displacement slug adopts a second-strength micro-viscous liquid system, the viscosity of the first-strength micro-viscous liquid system and the viscosity of the second-strength micro-viscous liquid system are both greater than that of crude oil, the first strength is higher than the second strength, and the displacement slug samples formation water;
s3, respectively calculating the injection pressure value and the injection displacement of the three-section water plugging slug according to the production pressure gradient, the injection-production ratio and the stratum permeability by combining the plugging agent dosage calculated in the step S1 and the total injection amount calculated according to the oil reservoir pore volume in the step S2;
and S4, sequentially injecting three sections of water plugging slugs into the stratum of the oil well to be displaced according to the calculated injection displacement to perform displacement construction, injecting the partition plate slugs into an oil-water interface, spreading and solidifying to block bottom water, and displacing the displacement slugs above the partition plate slugs along the transverse direction through a lateral displacement technology to drive residual oil between the large bottom water reservoir wells.
Preferably, the injection amount of the partition plate slug calculated in the step S3 is 55-65% of the total injection amount, and the injection amount of the displacement slug is 28-43% of the total injection amount; the injection amount of the displacement slug is 4-8% of the total injection amount.
Preferably, the first strength micro-mucus system and the second strength micro-mucus system of the step S2 each comprise a polymer, a cross-linking agent, an auxiliary agent and formation water, wherein the polymer is a high temperature and high salt resistant polymer, any one of AP-P3 polymer, AM-AMPS polymer or other salt resistant polymer is adopted, and the cross-linking agent is ZX-1; the auxiliary agent is LGY.
Preferably, the first and second intensity micro-mucus systems of step S2 are both micro-mucus systems, and the formula of each component is as follows: 0.2-0.3% of polymer, 0.05-0.075% of ZX-1, 0.05-0.5% of LGY and the balance of formation water; the polymer proportion and the auxiliary agent proportion of the first-strength micro-mucus system are higher than those of the second-strength micro-mucus system.
Preferably, the formulation of the first strength micro-mucus system is: 0.3% of polymer, 0.05% of ZX-1, 0.5% of LGY and the balance of formation water, wherein the first strength micro-viscous liquid system is used for blocking bottom water to realize channeling sealing and plugging;
the formula of the second-strength micro-viscous liquid system comprises 0.2% of polymer, 0.05% of ZX-1 and 0.05% of LGY, and the balance is formation water, and the second-strength micro-viscous liquid system is used for tackifying and displacing and driving residual oil between large-bottom water reservoir wells.
Preferably, the amount of the plugging agent calculated in the step S1 is the total amount of the first-strength micro-mucus system and the second-strength micro-mucus system, and the total amount of the first-strength micro-mucus system and the second-strength micro-mucus system is 0.3-0.4 PV oil layer.
Preferably, the total amount of the first and second strength micro-mucus systems is 0.3PV oil layer.
Preferably, the first strength micro-viscous liquid system and the second strength micro-viscous liquid system are injected and produced by an oil well in the step S4.
The invention has the beneficial effects that:
the invention provides a method for enhancing the efficiency of lateral flooding between wells of a bottom water reservoir, which aims at the problems of enrichment of residual oil between wells of the bottom water reservoir and no effective treatment means, develops the research of a preposed clapboard and lateral water flooding technology, designs a three-section water plugging slug after a three-dimensional bottom water reservoir physical model device is established and the dosage of a plugging agent is calculated, and designs a clapboard slug, a displacement slug and a displacement slug three-section water plugging slug, wherein the clapboard slug adopts a first strength micro-viscous liquid system, the displacement slug adopts a second strength micro-viscous liquid system, the viscosities of the first strength micro-viscous liquid system and the second strength micro-viscous liquid system are both greater than the viscosity of crude oil, the first strength is higher than the second strength, namely, the clapboard slug and the displacement slug both adopt micro-viscous liquid systems, the viscosity of the micro-viscous liquid systems is slightly greater than the viscosity of the crude oil, the clapboard slug adopts a high strength micro-viscous liquid system, the displacement slug adopts a low strength micro-viscous liquid system, the high strength and the low strength are relative to each other, after the injection pressure value and the injection displacement of the three-section water plugging slug are respectively calculated, the three-section water plugging slug is sequentially injected for displacement construction, wherein the partition slug is injected to an oil-water interface to be spread and solidified so as to block bottom water, the displacement slug is transversely displaced above the partition slug through a lateral displacement technology so as to drive residual oil between wells of a large bottom water reservoir, so that the efficient displacement of the residual oil between the wells is realized, and the method can be used for various reservoir conditions such as a bottom water reservoir, interwell displacement, oil well injection, an oil well and the like. After a high-strength micro-viscous liquid system is injected, due to the difference of fluidity, an obvious partition plate can be formed at an oil-water interface, injected water is forced to be diverted to displace an oil layer on the upper part of bottom water, residual oil between wells is improved, and the recovery condition is obviously better than that of nitrogen foam injection and nitrogen injection.
Drawings
FIG. 1 is a flow chart of the interwell lateral displacement synergy method of the large-bottom water reservoir of the invention.
FIG. 2 is a construction schematic diagram of the interwell lateral flooding synergistic method for the large-bottom water reservoir.
Detailed Description
For a clearer understanding of the contents of the present invention, reference will be made to the accompanying drawings and examples.
The invention relates to a method for lateral drive synergism between large-bottom water oil reservoirs, the flow of which is shown in figure 1, and the method comprises the following steps: s1, establishing a three-dimensional bottom water oil reservoir physical model device according to the relative thickness of a stratum and an oil layer where an oil well to be displaced is located, the inter-well distance and the relative size of bottom water parameters, and calculating the using amount of a plugging agent; s2, designing a partition plate slug, a displacement slug and a displacement slug three-section water plugging slug, and calculating the total injection amount according to the pore volume of the oil reservoir; the separator slug adopts a first-strength micro-viscous liquid system, the displacement slug adopts a second-strength micro-viscous liquid system, the viscosity of the first-strength micro-viscous liquid system and the viscosity of the second-strength micro-viscous liquid system are both greater than that of the crude oil, the first strength is higher than the second strength, and the displacement slug samples formation water; s3, respectively calculating the injection pressure value and the injection displacement of the three-section water plugging slug according to the production pressure gradient, the injection-production ratio and the stratum permeability by combining the plugging agent dosage calculated in the step S1 and the total injection amount calculated according to the oil reservoir pore volume in the step S2; and S4, injecting three sections of water plugging slugs into the stratum of the oil well to be displaced in sequence according to the calculated injection displacement to perform displacement construction, as shown in a construction principle diagram of fig. 2, injecting the partition slugs into an oil-water interface, spreading and solidifying to form a partition 1 to block bottom water, and displacing the displacement slugs transversely (such as a transverse channel 2 shown in fig. 2) above the partition slugs through a lateral displacement technology to drive residual oil between wells of the large-bottom water reservoir. That is, after the high-strength micro-viscous liquid system is injected, due to the difference of fluidity, the obvious partition plate 1 can be formed at the oil-water interface, the injected water is forced to be diverted to displace the upper oil layer of the bottom water, and the residual oil between wells is improved. According to the invention, by combining the preposed partition plate and the lateral displacement technology, the residual oil between wells is efficiently displaced, the residual oil between wells is improved, and the later recovery rate is greatly improved.
Further preferably, the amount of the plugging agent calculated in the step S1 is the total amount of the first strength micro mucus system and the second strength micro mucus system, and the total amount of the first strength micro mucus system and the second strength micro mucus system is 0.3 to 0.4PV oil layer, and further preferably 0.3PV oil layer.
The total injection amount calculated in the step S2 is the total dosage of the first strength micro-mucus system and the second strength micro-mucus system calculated in the step S1, and the total dosage of the displacement slug formation water is added; s3, respectively calculating the injection displacement of the three sections of water plugging slugs, and further calculating that the injection quantity of the partition plate slug is 55-65% of the total injection quantity, and the injection quantity of the displacement slug is 28-43% of the total injection quantity; the injection amount of the displacement slug is 4-8% of the total injection amount.
The three sections of water plugging slugs are respectively a partition plate slug, a displacement slug and a displacement slug, preferably, a first strength micro-mucus system adopted by the partition plate slug and a second strength micro-mucus system adopted by the displacement slug belong to micro-mucus systems, the viscosity of the micro-mucus system is slightly larger than that of crude oil, the viscosity of the crude oil is 2 mPa.S, and the viscosity of the micro-mucus system can be 5 mPa.S.
Preferably, the micro-mucus system comprises a polymer, a cross-linking agent, an auxiliary agent and formation water, wherein the polymer is a high-temperature and high-salt resistant polymer, any one of an AP-P3 polymer, an AM-AMPS polymer or other salt resistant polymers can be selected, and the cross-linking agent is preferably ZX-1; the adjuvant is preferably LGY. The formula of each component in the micro mucus system is as follows: 0.2-0.3% of polymer, 0.05-0.075% of ZX-1, 0.05-0.5% of LGY and the balance of formation water; compared with the second-strength micro-mucus system, the proportion of the polymer and the proportion of the auxiliary agent in the first-strength micro-mucus system are higher than those in the second-strength micro-mucus system, and the proportion of the cross-linking agent in the first-strength micro-mucus system and the proportion of the auxiliary agent in the second-strength micro-mucus system are the same. The first intensity is higher than the second intensity, i.e. the first intensity micro mucus system may also be referred to as a high intensity micro mucus system and the second intensity micro mucus system may also be referred to as a low intensity micro mucus system, i.e. the separator segment uses a high intensity micro mucus system and the displacement segment uses a low intensity micro mucus system, where high and low intensity are relative to each other.
Further, the first strength micro-mucus system is formulated as: 0.3% of polymer, 0.05% of ZX-1, 0.5% of LGY and the balance of formation water, wherein the first strength micro-viscous liquid system is used for blocking bottom water and achieving channeling sealing and plugging. The formula of the second-strength micro-viscous liquid system comprises 0.2% of polymer, 0.05% of ZX-1 and 0.05% of LGY, and the balance is formation water, and the second-strength micro-viscous liquid system is used for tackifying and displacing and driving residual oil between large-bottom water reservoir wells.
The above formulation is only preferred, and the formulations of the components of the first and second intensity mucus systems can be adjusted appropriately.
Further, the invention relates to a method for lateral displacement and synergy between the undersea water and oil reservoirs, wherein the first strength micro-viscous liquid system and the second strength micro-viscous liquid system are injected into and produced from the oil wells in the step S4. The method is substantially different from the existing displacement concept which adopts water well injection and oil well production.
Taking the Tahe TK202H well as an example, the method comprises the following specific steps:
s1, establishing a three-dimensional bottom water oil reservoir physical model device according to the relative thickness of a stratum oil layer where an oil well to be displaced is located, the inter-well distance and the relative size of bottom water parameters, and calculating the using amount of a plugging agent to prepare the plugging agent;
S1A, according to a formula: stirring 0.3% of polymer, 0.05% of ZX-1, 0.5% of LGY and the balance of formation water to prepare a high-strength micro-viscous liquid system;
S1B, preparing a low-strength micro-mucus system by stirring according to a formula, namely 0.2% of polymer, 0.05% of ZX-1, 0.05% of LGY and the balance of formation water;
s2, designing a three-section water plugging slug, and designing an injection total amount of a 0.3PV oil layer according to the pore volume of the oil reservoir;
s3, designing the injection pressure value and the injection displacement of the plugging agent according to the production pressure gradient, the injection-production ratio and the stratum permeability;
s4, sequentially injecting three sections of water plugging slugs into the stratum of the oil well to be displaced for displacement construction;
S4A, injecting a high-strength micro-mucus system, namely a diaphragm slug into the stratum, wherein the injection amount of the high-strength micro-mucus system is 60% of the total injection amount;
S4B, injecting a low-strength micro-mucus system, namely a displacement slug, into the stratum, wherein the injection amount is 35% of the total injection amount;
S4C, injecting formation water, namely a displacement slug, into the stratum, wherein the injection amount is 5% of the total injection amount;
through two stages of trial injection and formal injection, the total amount of the injected medicament is 8677, wherein: the high-strength micro-mucus system comprises 3197 parts of low-strength micro-mucus (namely a second-strength micro-mucus system adopted by a displacement slug, also called a low-strength micro-mucus system), 5480 parts of high-strength micro-mucus (namely a first-strength micro-mucus system adopted by a partition slug, also called a high-strength micro-mucus system), the maximum pressure is 24.3MPa, and the recovery ratio is improved by 14%.
It should be noted that the above-mentioned embodiments enable a person skilled in the art to more fully understand the invention, without restricting 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 various changes and modifications can be made therein without departing from the spirit and scope of the invention.
Claims (8)
1. A method for lateral drive synergism between large-bottom water oil reservoirs is characterized by comprising the following steps:
s1, establishing a three-dimensional bottom water oil reservoir physical model device according to the relative thickness of a stratum and an oil layer where an oil well to be displaced is located, the inter-well distance and the relative size of bottom water parameters, and calculating the using amount of a plugging agent;
s2, designing a partition plate slug, a displacement slug and a displacement slug three-section water plugging slug, and calculating the total injection amount according to the pore volume of the oil reservoir; the partition plate slug adopts a first-strength micro-viscous liquid system, the displacement slug adopts a second-strength micro-viscous liquid system, the viscosity of the first-strength micro-viscous liquid system and the viscosity of the second-strength micro-viscous liquid system are both greater than that of crude oil, the first strength is higher than the second strength, and the displacement slug samples formation water;
s3, respectively calculating the injection pressure value and the injection displacement of the three-section water plugging slug according to the production pressure gradient, the injection-production ratio and the stratum permeability by combining the plugging agent dosage calculated in the step S1 and the total injection amount calculated according to the oil reservoir pore volume in the step S2;
and S4, sequentially injecting three sections of water plugging slugs into the stratum of the oil well to be displaced according to the calculated injection displacement to perform displacement construction, injecting the partition plate slugs into an oil-water interface, spreading and solidifying to block bottom water, and displacing the displacement slugs above the partition plate slugs along the transverse direction through a lateral displacement technology to drive residual oil between the large bottom water reservoir wells.
2. The method for enhancing the lateral displacement efficiency of the undersea water oil reservoir wells according to claim 1, wherein the injection amount of the partition plate slug calculated in the step of S3 is 55-65% of the total injection amount, and the injection amount of the displacement slug is 28-43% of the total injection amount; the injection amount of the displacement slug is 4-8% of the total injection amount.
3. The method for lateral displacement and synergism between subsea wells according to claim 1 or 2, wherein the first and second strength micro-mucus systems of step S2 each comprise a polymer, a cross-linking agent, an auxiliary agent and formation water, wherein the polymer is a high temperature and high salt resistant polymer, any one of AP-P3 polymer, AM-AMPS polymer or other salt resistant polymer is used, and the cross-linking agent is ZX-1; the auxiliary agent is LGY.
4. The method for lateral displacement and synergism between undersea water and oil reservoirs according to claim 3, wherein the first-strength micro-viscous liquid system and the second-strength micro-viscous liquid system of the step S2 belong to micro-viscous liquid systems, and the formula of each component is as follows: 0.2-0.3% of polymer, 0.05-0.075% of ZX-1, 0.05-0.5% of LGY and the balance of formation water; the polymer proportion and the auxiliary agent proportion of the first-strength micro-mucus system are higher than those of the second-strength micro-mucus system.
5. The method for lateral flooding synergy between undersea water and oil-bearing wells according to claim 4, wherein the formulation of the first strength micro-viscous liquid system is: 0.3% of polymer, 0.05% of ZX-1, 0.5% of LGY and the balance of formation water, wherein the first strength micro-viscous liquid system is used for blocking bottom water to realize channeling sealing and plugging;
the formula of the second-strength micro-viscous liquid system comprises 0.2% of polymer, 0.05% of ZX-1 and 0.05% of LGY, and the balance is formation water, and the second-strength micro-viscous liquid system is used for tackifying and displacing and driving residual oil between large-bottom water reservoir wells.
6. The method for enhancing lateral displacement between undersea water and oil-bearing wells according to claim 1, wherein the amount of the plugging agent calculated in the step S1 is the total amount of the first-strength micro-viscous liquid system and the second-strength micro-viscous liquid system, and the total amount of the first-strength micro-viscous liquid system and the second-strength micro-viscous liquid system is 0.3-0.4 PV oil layer.
7. The method of claim 6, wherein the first and second strength micro-viscous liquid systems are used in a total amount of 0.3PV layer.
8. The method of claim 6, wherein the first and second high-strength micro-viscous fluid systems are produced by well injection and well production in step S4.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202011002770.1A CN114427376B (en) | 2020-09-22 | 2020-09-22 | Method for enhancing lateral drive between wells of large-bottom water reservoir |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202011002770.1A CN114427376B (en) | 2020-09-22 | 2020-09-22 | Method for enhancing lateral drive between wells of large-bottom water reservoir |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN114427376A true CN114427376A (en) | 2022-05-03 |
| CN114427376B CN114427376B (en) | 2024-04-26 |
Family
ID=81310282
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202011002770.1A Active CN114427376B (en) | 2020-09-22 | 2020-09-22 | Method for enhancing lateral drive between wells of large-bottom water reservoir |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN114427376B (en) |
Citations (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101787864A (en) * | 2010-03-15 | 2010-07-28 | 中国石油集团川庆钻探工程有限公司 | Method for plugging water from oil reservoir fractured water logging oil well developed by injecting water into low-permeable reservoir stratum |
| CN102373914A (en) * | 2010-08-25 | 2012-03-14 | 中国石油天然气股份有限公司 | Deep profile control method for fractured oil reservoir |
| CN103498643A (en) * | 2013-10-23 | 2014-01-08 | 天津亿利科能源科技发展股份有限公司 | Composite slug deep water plugging method for oil pool with high water content |
| CN103527161A (en) * | 2012-07-03 | 2014-01-22 | 中国石油化工股份有限公司 | Thermal recovery horizontal well water shut-off and profile control method |
| CN109236253A (en) * | 2018-09-07 | 2019-01-18 | 中国石油大学(北京) | A kind of method of activation of microorganism oil reservoir and cross-linked polymer displacement remaining oil |
| WO2019024531A1 (en) * | 2017-07-31 | 2019-02-07 | 中国石油天然气股份有限公司 | Method for deep profile modification and flooding of low-permeability reservoir |
| CN110029973A (en) * | 2018-01-11 | 2019-07-19 | 中国石油化工股份有限公司 | A kind of method that multiple dimensioned frozen glue dispersion improves reservoir water drive effect |
| CN110952952A (en) * | 2019-12-18 | 2020-04-03 | 成都新驱势石油技术开发有限公司 | Low-permeability reservoir deep profile control and flooding method |
| CN111577231A (en) * | 2020-05-14 | 2020-08-25 | 中国石油天然气股份有限公司 | Method for improving water plugging effect of flooded oil well through reverse profile control and flooding |
-
2020
- 2020-09-22 CN CN202011002770.1A patent/CN114427376B/en active Active
Patent Citations (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101787864A (en) * | 2010-03-15 | 2010-07-28 | 中国石油集团川庆钻探工程有限公司 | Method for plugging water from oil reservoir fractured water logging oil well developed by injecting water into low-permeable reservoir stratum |
| CN102373914A (en) * | 2010-08-25 | 2012-03-14 | 中国石油天然气股份有限公司 | Deep profile control method for fractured oil reservoir |
| CN103527161A (en) * | 2012-07-03 | 2014-01-22 | 中国石油化工股份有限公司 | Thermal recovery horizontal well water shut-off and profile control method |
| CN103498643A (en) * | 2013-10-23 | 2014-01-08 | 天津亿利科能源科技发展股份有限公司 | Composite slug deep water plugging method for oil pool with high water content |
| WO2019024531A1 (en) * | 2017-07-31 | 2019-02-07 | 中国石油天然气股份有限公司 | Method for deep profile modification and flooding of low-permeability reservoir |
| CN110029973A (en) * | 2018-01-11 | 2019-07-19 | 中国石油化工股份有限公司 | A kind of method that multiple dimensioned frozen glue dispersion improves reservoir water drive effect |
| CN109236253A (en) * | 2018-09-07 | 2019-01-18 | 中国石油大学(北京) | A kind of method of activation of microorganism oil reservoir and cross-linked polymer displacement remaining oil |
| CN110952952A (en) * | 2019-12-18 | 2020-04-03 | 成都新驱势石油技术开发有限公司 | Low-permeability reservoir deep profile control and flooding method |
| CN111577231A (en) * | 2020-05-14 | 2020-08-25 | 中国石油天然气股份有限公司 | Method for improving water plugging effect of flooded oil well through reverse profile control and flooding |
Non-Patent Citations (1)
| Title |
|---|
| 邓爱居等: "边水驱厚油层复合堵水技术", 油气井测试, vol. 25, no. 5, 25 October 2016 (2016-10-25), pages 55 - 57 * |
Also Published As
| Publication number | Publication date |
|---|---|
| CN114427376B (en) | 2024-04-26 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN105298438B (en) | More fine profile control methods in round polymer gel deep | |
| EP2284359A1 (en) | Method of enhanced oil recovery from geological reservoirs | |
| WO2019223346A1 (en) | Nitrogen composite huff-puff method for closed fault block oil reservoir | |
| CN108678715B (en) | A kind of method that viscoelastic foam drives exploitation deep-layer heavy crude reservoir | |
| CN100485160C (en) | Nitrogen foam adjusting-actuating segment plug injection technique | |
| CN102051161B (en) | Thick oil huff and puff deep channel blocking system and injection method thereof | |
| CN103087699A (en) | Sand-carrying profile control agent composition of fracture-cave type oil deposit and profile control method of profile control agent | |
| CN110552671A (en) | Method for realizing high-efficiency development of heavy oil reservoir by utilizing dimethyl ether to assist CO 2 flooding | |
| CN101314712A (en) | Microsphere oil displacement profile control agent, displacement of reservoir oil system and displacement of reservoir oil method | |
| CN101314711A (en) | Elastic particle oil displacement profile control agent, displacement of reservoir oil system and displacement of reservoir oil method | |
| CN101915079A (en) | Integrated de-plugging yield increasing process | |
| US4129182A (en) | Miscible drive in heterogeneous reservoirs | |
| RU2569101C1 (en) | Method of decrease of water inflow to horizontal wells | |
| CN109751023A (en) | Drive, tune, the stifled integration that wide scope permanently reduces blowhole improve recovery ratio method | |
| RU2515675C1 (en) | Isolation method of water influx to oil producer | |
| CN114427376A (en) | Lateral drive synergistic method between large-bottom water oil reservoir wells | |
| CN108643856A (en) | A kind of radial well guiding blocking agent injection oilwell water shutoff method | |
| CN104481478B (en) | Gather the method altered and its inorganic agent used in macropore plugging on polymer flooding correspondence oil well | |
| CA1238850A (en) | Method for recovering hydrocarbons from fractured or highly stratified low viscosity subsurface reservoirs | |
| CN107143319A (en) | The cold method adopted of shallow oil reservoir reducing thick oil viscosity | |
| RU2286447C2 (en) | Method for water influx isolation in horizontal producing well bore | |
| US3548940A (en) | Method for recovery of hydrocarbons from a subterranean formation previously produced by solution gas drive | |
| RU2730705C1 (en) | Development method of super-viscous oil deposit with water-oil zones | |
| CN115828639B (en) | Profile control and profile control combined process scheme adjustment method | |
| US20230265749A1 (en) | Methodology to improve the efficiency of gravity drainage co2 gas injection processes |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |