CN107237618B - Method for increasing yield and controlling water of bottom water sandstone gas reservoir - Google Patents
Method for increasing yield and controlling water of bottom water sandstone gas reservoir Download PDFInfo
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- 206010017076 Fracture Diseases 0.000 claims description 53
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- WKBOTKDWSSQWDR-UHFFFAOYSA-N Bromine atom Chemical class [Br] WKBOTKDWSSQWDR-UHFFFAOYSA-N 0.000 claims description 3
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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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
- E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
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Abstract
The invention relates to the technical field of hydraulic fracturing modification of oil and gas reservoirs, in particular to a method suitable for increasing production and controlling water of a bottom water sandstone gas reservoir. Which comprises the following steps: step A: evaluating characteristic parameters of the longitudinal ground stress profile and the natural fracture; and B: analyzing the control factors of the seam making height and the supporting height; the method comprises the following steps: pretreating the reservoir by using acid liquor, and controlling the longitudinal overextension of the initial seam height; step two: injecting the RPM fracturing fluid serving as a fracturing pre-pad fluid into a stratum to realize water resistance; step three-five: the variable parameter combined fracturing process technology adopts different viscosity liquids to carry proppants with different particle sizes and densities for variable displacement construction, and controls the extension and expansion of cracks and the reasonable and effective laying of the proppants; step six: completely displacing the propping agent in the shaft to the crack seam by using low-viscosity slippery liquid and other low-viscosity liquid; step seven: and if the bottom water layer is pressed open in the construction, after the fracturing construction is finished and the crack is closed, injecting weighted RPM fracturing fluid into the crack in a pressure limiting mode to prevent water in the bottom water layer from jumping upwards.
Description
Technical Field
The invention relates to the technical field of hydraulic fracturing modification of oil and gas reservoirs, in particular to a method which is suitable for increasing the fracturing yield of a bottom water sandstone gas reservoir and effectively controlling water.
Background
The physical property conditions of the tight sandstone bottom water gas reservoir are generally poor, most of gas wells can obtain industrial capacity only through fracturing modification, and the fracturing modification technology becomes one of core technologies for increasing the yield of the reservoir and effectively developing the reservoir. The tight sandstone bottom water-gas reservoir is close to the bottom water layer, so that the water layers are easy to communicate in the fracturing modification process, the water yield after fracturing is greatly increased, the water lock effect is serious, and the effective output of gas is restricted. At present, the fracturing modification of the reservoir is mainly characterized in that the problems of different degrees exist in the control method of the seam forming height and the supporting height, so that the final yield and water control effect is poor, and the method is specifically shown in the following aspects:
1) The fracturing design and construction scale is generally large, so that the joint height of the crack excessively extends downwards in the longitudinal direction;
2) The fracturing construction displacement is large, so that the bottom hole pressure is easily rapidly gathered and raised, the seam height is caused to extend too fast and too high, and particularly when the stress difference between a fracturing target reservoir and the upper and lower interlayers is not balanced, the too high displacement can cause the seam height to extend faster to the vertical direction with small stress difference;
3) The viscosity design and application of the fracturing fluid are not reasonable enough, a single fracturing fluid system or a viscosity fracturing fluid system is adopted in the whole process of most fracturing construction, and the viscosity of the fracturing fluid is generally higher, so that the excessive extension of the seam height is caused;
4) The optimization of the propping agent is not enough, the type of the propping agent adopted in the construction is single, the density is relatively high, and once the water channeling layer is pressed when the height is out of control, the fracture flow conductivity of the propping agent supported in the water layer is too high, the water conductivity is too high, and the water locking effect is aggravated.
In order to solve a plurality of problems faced by fracturing of a compact sandstone bottom water gas reservoir and realize effective modification of the reservoir, a method for improving the effectiveness of fracturing modification on the basis of effective water prevention and water control in the fracturing process of the bottom water sandstone gas reservoir needs to be provided.
Disclosure of Invention
The invention provides a method and a process for improving the effectiveness of fracturing modification on the basis of effective water prevention and water control in the bottom water sandstone gas reservoir fracturing process. The method for increasing production and controlling water of the bottom water sandstone gas reservoir follows the technical idea of prevention and treatment, and avoids pressing and cracking a water layer to the maximum extent by means of ground stress profile fine analysis, main control factor analysis of joint forming height and supporting height, fracturing fluid using a novel Relative Permeability Regulator (RPM) and variable parameter combined fracturing technology, improves the effectiveness of fracturing of the reservoir, achieves the aim of gas production and increasing production on the basis of water prevention and control, and improves the fracturing modification effect and the reservoir utilization degree of the reservoir.
Therefore, the invention provides a method for increasing production and controlling water of a bottom water sandstone gas reservoir, which comprises the following steps:
The method comprises the following steps: and (4) pretreating the reservoir by using acid liquor.
Step two: the RPM fracturing fluid is injected into the formation as a pre-pad for fracturing.
Step three: performing fracturing construction by using a first fracturing fluid carrying 70/140-mesh proppant, wherein the discharge capacity of the first fracturing fluid is 2.0-3.0m during the fracturing construction3The first fracturing fluid is a low-viscosity fracturing fluid (for example, the first fracturing fluid can be slick water and/or non-crosslinked linear glue), the viscosity of the first fracturing fluid is below 20mPa.s, and the bulk density of the first fracturing fluid carrying 70/140 mesh of propping agent is 1.5-1.8g/cm3(ii) a For example, generally, the viscosity of the first fracturing fluid is 10mpa.s or less; if the natural fracture of the reservoir is relatively developed, the viscosity of the liquid can be properly increased according to the results of the fluid loss test and the simulation of the fracturing fracture, for example, the viscosity is 10-20 mPa.s.
Step four: performing fracturing construction by using a second fracturing fluid carrying 40/70-mesh proppant, wherein the discharge capacity of the second fracturing fluid is 3.0-4.0m during the fracturing construction3A second fracturing fluid which is a medium viscosity fracturing fluid (which may be a fracturing fluid base fluid and/or a weakly cross-linked fracturing fluid, for example), has a viscosity of 30-60mPa.s, and carries a proppant of 40/70 meshthe volume density of the second fracturing fluid is 1.25-1.5g/cm3(ii) a And the viscosity of the second fracturing fluid can be adjusted according to the requirement of the fracturing process.
Step five: performing fracturing construction by using a third fracturing fluid carrying a 30/50-mesh proppant, wherein the discharge capacity of the third fracturing fluid is 4.0-6.0m during the fracturing construction3The third fracturing fluid is a high-viscosity fracturing fluid (for example, a cross-linking fracturing fluid), the viscosity of the third fracturing fluid is 120-150mPa.s, and the volume density of the third fracturing fluid carrying the 30/50 mesh proppant is 1.05-1.25g/cm3. The discharge capacity of the third fracturing fluid can optimize and adjust the viscosity of the fluid according to the requirements of the fracturing process and the requirements of adding the proppant at the later high sand ratio stage.
Step six: and completely displacing the propping agent in the shaft to the crack gap by using low-viscosity liquid such as low-viscosity slickwater and the like, wherein the viscosity of the low-viscosity liquid is less than 10mPa.s, and the dosage of the low-viscosity liquid is the sum of the volume of the shaft and the volume of a ground pipeline.
Step seven: if the bottom water layer is pressed open due to improper construction or other factors in the construction, weighted RPM fracturing fluid is injected into the cracks after the cracks are closed after the fracturing construction is finished, and the injection pressure is lower than the wellhead pressure when the cracks are closed so as to prevent water in the bottom water layer from flowing upwards.
When the variable parameter combined fracturing technology is used for construction, the low-discharge and low-viscosity fracturing fluid can effectively control the initial extension of the height of the manufacturing seam; through the matching of the variable-density and variable-particle-size propping agents, the high-density and small-particle-size propping agents are settled at the bottom of the seam to control the seam to run upwards; the high-viscosity fracturing fluid and the low-density proppant at the later stage are matched, so that the proppant is mainly controlled to be supported at the middle upper part of a reservoir, and the great increase of water content caused by that most of the proppant is settled to the bottom of a seam is prevented.
in a specific embodiment, the method further comprises steps a and B prior to step one, wherein step a: evaluating characteristic parameters of the longitudinal ground stress profile and the natural fracture; and B: the control factors of seam making height and support height are analyzed.
In one embodiment, the characteristic parameters of the longitudinal stress profile and the natural fracture include lithology, physical properties, rock mechanics, longitudinal stress profile, natural fracture development characteristics, and the like, and the purpose of the characteristic parameters is to provide comprehensive and accurate basic data for the fracturing process and the fluid optimization design.
In one embodiment, the control factors of the seam making height and the supporting height comprise uncontrollable geological parameters and controllable fracturing construction parameters, preferably the uncontrollable geological parameters comprise longitudinal storage interlayer stress difference, longitudinal storage interlayer Young modulus difference, fracture toughness and the like; preferably, the controllable fracturing construction parameters comprise the injection discharge, viscosity and injection volume of the first fracturing fluid, the second fracturing fluid and the third fracturing fluid, the type and the addition of a propping agent, the sand concentration of sand added in construction and the like.
In one embodiment, the uncontrolled geological parameters and the controlled fracture construction parameters are analyzed for single factor sensitivity using fracture simulation software, wherein preferably the fracture simulation software is selected from at least one of commercial fracture simulation software such as FracPro, StimPlan, and GOHFER.
Wherein the uncontrollable geological parameters can be controlled by a pre-pressure fine well selection.
Generally, the influence degree of the viscosity and the discharge capacity of the fracturing fluid on the joint-making height is relatively high, and parameters such as the density and the particle size of a propping agent and the sand concentration (sand-liquid ratio) of sand adding in construction have large influence on the supporting height; in addition, to prevent the bottom aqueous layer from being pressed open, the perforated section should be selected as far away from the bottom aqueous layer as possible.
In one embodiment, in the first step, the acid solution and injection parameters are selected according to the reservoir conditions; preferably the conditions of the reservoir comprise the mineral composition of the reservoir; preferably, the acid solution comprises hydrochloric acid and/or earth acid; preferably, the injection parameters comprise the dosage of the acid liquor, and more preferably, the discharge capacity of the acid liquor is 0.5-1.3m3And/min. As a general case, the discharge amount of the acid liquid can be 0.5-1.0m3Min; however, it is not limited toWhen natural fractures of reservoirs are relatively developed, the acid liquor discharge capacity can be properly increased by about 20-30%, for example, the acid liquor discharge capacity can be 1.0-1.3m3/min。
The acid liquor is selected by considering the mine characteristics of a sufficient reservoir, conventional hydrochloric acid or earth acid can be used, and the formula of the acid liquor is optimized for an acid-sensitive reservoir to prevent acid sensitivity. The acid liquor dosage can be comprehensively determined according to the fracturing crack simulation and the specific well condition and the fracturing process requirements.
In one embodiment, the RPM pre-pad fracturing fluid in step two is a relative permeability modifier fracturing fluid; preferably, the amount of the relative permeability modifier fracturing fluid is determined based on simulation results of commercial fracture simulation software such as FracPro, StimPlan and GOHFER, and more preferably, the fracture length of the RPM pre-pad is more than 60% of the total fracture length designed by the fracture simulation software.
Wherein, the Relative Permeability Modifier (RPM) fracturing fluid for changing the phase Permeability is a liquid system similar to the organic combination of the fracturing technology and the water plugging technology; when the fracturing fluid encounters water, the liquid molecules relax to block the water flow channel; when the fracturing fluid meets gas or oil, liquid molecules shrink, and the blocking effect on the gas or oil is almost negligible.
In the fracturing construction, the RPM fracturing fluid is used as a pre-pad fluid; in the process of fracturing and crack making, the RPM fracturing fluid is always on the front edge of the crack and percolates in a certain distance in the vertical direction of the crack wall, so that the effect of the RPM fracturing fluid is achieved near the crack wall, and finally the purposes of water control and gas increase are achieved in the process of back drainage and production after the fracturing.
The action period of the RPM fracturing fluid is related to the percolation depth and the residence time of the RPM fracturing fluid in the stratum, and the larger the percolation depth and the longer the residence time of the RPM fracturing fluid are, the better the water control and gas increase effects are.
The dosage of the relative permeability regulator fracturing fluid generally requires that the length of the pre-pad fluid fracture is at least more than 60% of the total fracture length designed by fracture simulation software; if the natural cracks of the fracturing target layer develop comparatively, filtration reducing measures such as adding a thickening agent with a certain proportion in RPM or adding solid filtration reducing agents such as powder pottery and the like in construction can be adopted.
Therefore, in one embodiment, the construction time in the third step is 60-70% of the total height expected by the design with the seam making height, and the seam making length is 20-30% of the total height expected by the design.
The construction time of each stage of the third, fourth and fifth steps is determined based on the simulation result of commercial crack simulation software such as FracPro, StimPlan and GOHFER; as mentioned above, the construction time in the third step is based on that the height of the seam making reaches 60-70% of the total height expected by the design, and the length of the seam making reaches 70-80% of the total height expected by the design of the crack simulation software; and after the third step is finished, considering the difficulty degree of fracturing construction, if the width of the fracture is narrow and sand addition is difficult, the construction time of the fourth step can be properly increased, otherwise, the construction time of the fifth step can be properly increased.
If the water layer is pressed open due to improper construction or other factors in the construction, water control treatment work after pressing open the water layer is carried out; the specific method comprises the following steps: after fracturing construction is finished and the fracture is closed, the weighted RPM fracturing fluid is injected into the fracture by adopting a pressure limiting (the injection pressure is lower than the wellhead pressure when the fracture is closed) measure without limiting the discharge capacity, the discharge capacity is strictly controlled in the injection process, and the closed fracture is prevented from opening again to cause the sinking of a large amount of propping agents.
Because the density of the weighted RPM fracturing fluid is high, the fracturing fluid is basically positioned in the bottom area of the crack after being injected into the crack, and therefore the fracturing fluid can be basically retained at the bottom of the crack for a long time and blocks water of a bottom water layer from rising upwards in the process of back-flowing and production of the fracturing fluid after being pressed as long as the production pressure difference is reasonably controlled.
In addition, the injection volume of the weighted RPM fracturing fluid can be designed according to the volume balance principle, the fracture volume from the bottom of a gas layer to the bottom of the fracture of a water layer below 2.0-3.0m is calculated, and the fracturing fluid is injected according to the amount which is 1.0-1.1 times of the fracture volume, so that the aim of covering the fracture volume communicated with the water layer as much as possible is fulfilled. Thus, in one embodiment, the injection volume of the weighted RPM fracturing fluid is from 2.0 to 3.0 meters below the bottom of the gas zone to 1.0 to 1.1 times the total volume of fractures at the bottom of the fractures of the water zone.
In one embodiment, the weighted RPM fracturing fluid contains bromine salts and/or nitrate salts. The bromine salt and/or nitrate are present in conventional amounts.
The method and the process technology for controlling water and increasing the yield of the bottom water sandstone gas reservoir have the advantages of simple thought and convenience in operation and implementation on site; the design and construction of the fracturing scheme of the bottom water sandstone gas reservoir are carried out according to the method, so that the problems of poor control of the fracturing and seam-making height, difficult effective support of a fracture system, prominent water lock effect, great increase of the water yield after fracturing, unsatisfactory yield increase and water control effect after fracturing and the like of the compact sandstone bottom water gas reservoir in the fracturing modification process can be effectively solved; on the basis of realizing the water control and gas increase targets, the supporting efficiency and the effective flow conductivity of the fractures in the reservoir are improved to the maximum extent, and the fracturing transformation effect and the reservoir exploitation degree of the reservoir are improved to the maximum extent.
The method and the process idea are successfully applied to the optimal design and test of the fracturing schemes of a plurality of bottom water sandstone gas reservoir blocks in China, and the application of field tests proves that the method has strong adaptability and pertinence, has operability and good application effect of the field tests.
Detailed Description
The present invention is further illustrated by the following examples, but the scope of the present invention is not limited to the following examples.
The various fluids used in the present invention, such as acid fluids, RPM fracturing fluids, low viscosity fracturing fluids, medium viscosity fracturing fluids, high viscosity fracturing fluids, and low viscosity slickwater, are commercially available from a variety of sources.
Example 1
The RPM fracturing fluid, the low-viscosity fracturing fluid, the medium-viscosity fracturing fluid, the high-viscosity fracturing fluid and the low-viscosity slickwater used in the embodiment are purchased from the institute of petroleum engineering technology of the national petrochemical industry, Inc.
The X well is a vertical well sandstone gas reservoir containing bottom water and positioned in a certain middle petrochemical gas field, the lithology of a target layer section is gray gravel-containing fine sandstone, the fracturing well section is 2857.7-2868.5m and 10.8m/1 layer, and the bottom water is present at a position 7.3m below the fracturing target layer; the average porosity of a target stratum core test is 9.3%, and the average permeability is 3.5mD, and the target stratum core test belongs to a low-porosity ultra-low permeability reservoir; the target layer pressure coefficient is 1.07, the stratum temperature is 106 ℃, and the method belongs to a normal-temperature normal-pressure gas reservoir. According to the stress profile explanation, the minimum principal stress mean value of the target layer of the well is 44.1MPa, the minimum principal stress number mean value of the upper interlayer of the target layer is 49.7MPa, and the minimum principal stress mean value of the lower interlayer is 47.2 MPa.
In order to evaluate the gas content and the productivity of a target sand group and carry out next exploration and evaluation work on the block, the fracturing scheme design and the field pilot test of the well are carried out by using the process method provided by the invention and combining the actual condition of the well, and the specific implementation method and the effect are as follows:
(1) The liquid system is preferably: the predicted reservoir temperature is about 106 ℃, and a fracturing fluid system capable of resisting 110 ℃ is preferred.
the formula of the slick water comprises the following components: 0.10 percent of drag reducer SRFR-2, 0.3 percent of clay stabilizer SRCS-2, 0.1 percent of cleanup additive SRCA-2 and the balance of clear water; apparent viscosity of 1.1-2.0 mPas, density of 0.99-1.02g/cm3(25 ℃), pH value is 6.5-7.5, drag reduction rate is 65-70%.
② the formula of the low-viscosity fracturing fluid: 0.2 percent of SRFP-1 thickening agent, 0.3 percent of SRCS-1 anti-swelling agent and 0.1 percent of SRCU-1 cleanup additive liquid; viscosity: 10-20 mP.s; pH value: 6-7.
formula of medium-viscosity fracturing fluid: 0.35 percent of SRFP-1 thickening agent, 0.3 percent of SRCS-1 anti-swelling agent and 0.1 percent of SRCU-1 cleanup additive; liquid viscosity: 30-40 mP.s; pH value: 6-7.
Fourthly, the formula of the high-viscosity fracturing fluid is as follows: 0.55 percent of SRFP-1 thickening agent, 0.2 percent of SRFC-1 cross-linking agent, 0.3 percent of SRCS-1 anti-swelling agent and 0.1 percent of SRCU-1 cleanup additive; liquid viscosity: 110-120 mP.s; pH value: 6-7.
(2) Acid liquor pretreatment: at 1.0m3Permin displacement 10m3The preposed earth acid has better compatibility with a reservoir.
(3) At 2.0m3Permin displacement injection 150m3RPM fracturing fluid.
(4) at 2.5m3Permin displacement injection 302m3Low viscosity fracturing fluid and in the process of injection, in a slug type sand adding modeAdding 70/140 mesh ceramic proppant, adding 70/140 mesh proppant 14.5m in total in a stepped increase mode (2% -4% -6% -8% -10%) with a slug type sand-adding starting sand ratio of 3%3。
(5) At 3.5-4.0m3Permin delivery 182m3Medium viscosity fracturing fluid, 40/70 mesh ceramic proppant is added in a slug type sand adding mode in the injection process, the 40/70 mesh proppant is added in a total amount of 14.4m proppant in a step increasing mode (12% -14% -16% -18%) with the slug type sand adding mode starting sand ratio of 6% and the sand ratio of the slug type sand adding mode3。
(6) At 4.5-5.5m3Permin displacement injection 240m3Adding 30/50 mesh ceramsite proppant in a slug type + continuous sand adding mode (after 24% sand ratio, the continuous mode is adopted) in the injection process, starting the sand ratio at 8% sand ratio in the slug type sand adding mode, and adding sand in a step increase mode (18% -20% -22%); the continuous sand adding starts with a sand ratio of 24 percent, and takes a sand ratio of 2 percent as step sand adding, wherein the highest sand ratio is 32 percent; a total of 40/70 mesh proppant of 37.5m is added3。
(7) A displacement stage: at 5.5m3Permin pump-in 14.0m3And (4) carrying out balance displacement on the slickwater, stopping the pump after the displacement is finished, measuring the pressure drop for 2 hours, and then finishing the well construction.
The pilot fracturing tests are carried out on the test well and a plurality of wells in the experimental area according to the steps, the site construction process is successful, and the pilot tests of the plurality of wells in the area prove that: by using the process method provided by the invention, through the well temperature measurement after fracturing and the simulation interpretation and analysis of the fractures, the fracture height in the fracturing construction is well controlled, the fractures mainly concentrate in reservoir fractures and extend, and the condition of out-of-control fracture height is not generated; the fracturing site construction process is successful, and the construction success rate is high; from the conditions of drainage after pressing and pilot production, no formation water is produced after pressing; from the statistic analysis of the after-pressure production capacity, the well pressure test in the area obtains good effects of increasing and stabilizing the production, and the daily capacity in the initial stage after the pressure test averagely reaches 40000m3d, the daily volume after stable birth is stable at 25000-30000m3D is about 2 to 4 times of the yield of the well implemented by the conventional fracturing process of the adjacent well, the initial yield after fracturing is obviously higher than that of the adjacent well, and the yield is decreased at a decreasing speedThe rate is obviously slower than that of an adjacent well, the effective period is obviously prolonged, the obvious effects of increasing and stabilizing yield are achieved, and the fracturing modification effect of the reservoir is improved.
Claims (23)
1. A method for increasing production and controlling water of a bottom water sandstone gas reservoir comprises the following steps:
The method comprises the following steps: pretreating a reservoir by using acid liquor;
Step two: injecting the RPM fracturing fluid into the stratum as a fracturing pre-pad fluid;
Step three: performing fracturing construction by using a first fracturing fluid carrying 70/140-mesh proppant, wherein the discharge capacity of the first fracturing fluid is 2.0-3.0m during the fracturing construction3The first fracturing fluid is low-viscosity fracturing fluid, the viscosity of the first fracturing fluid is below 20mPa.s, and the bulk density of the first fracturing fluid carrying 70/140 mesh of propping agent is 1.5-1.8g/cm3；
Step four: performing fracturing construction by using a second fracturing fluid carrying 40/70-mesh proppant, wherein the discharge capacity of the second fracturing fluid is 3.0-4.0m during the fracturing construction3The second fracturing fluid is a medium-viscosity fracturing fluid, the viscosity of the second fracturing fluid is 30-60mPa.s, and the bulk density of the second fracturing fluid carrying 40/70 mesh proppant is 1.25-1.5g/cm3；
step five: performing fracturing construction by using a third fracturing fluid carrying a 30/50-mesh proppant, wherein the discharge capacity of the third fracturing fluid is 4.0-6.0m during the fracturing construction3The third fracturing fluid is high-viscosity fracturing fluid, the viscosity of the third fracturing fluid is 120-150mPa.s, and the bulk density of the third fracturing fluid carrying 30/50 mesh proppant is 1.05-1.25g/cm3；
step six: completely displacing the proppant in the shaft to the crack gap by using low-viscosity liquid, wherein the viscosity of the low-viscosity liquid is below 10mPa.s, and the consumption of the low-viscosity liquid is the sum of the volume of the shaft and the volume of a ground pipeline;
Step seven: if the bottom water layer is pressed open, then at the end of the fracturing construction and after the fracture closes, a weighted RPM fracturing fluid is injected into the fracture at a pressure lower than the wellhead pressure at which the fracture closes to block water in the bottom water layer from channeling up.
2. the method of claim 1, wherein the low viscosity fracturing fluid is slickwater and/or a non-crosslinked linear gum.
3. The method of claim 1, wherein the medium viscosity fracturing fluid is a fracturing fluid base fluid and/or a weakly crosslinked fracturing fluid.
4. The method of claim 1, wherein the high viscosity fracturing fluid is a crosslinked fracturing fluid.
5. The method of claim 1, wherein the low viscosity liquid is a low viscosity slick water.
6. The method according to any one of claims 1-5, further comprising steps A and B prior to step one, wherein,
Step A: evaluating characteristic parameters of the longitudinal ground stress profile and the natural fracture;
and B: the control factors of seam making height and support height are analyzed.
7. The method of claim 6, wherein the characteristic parameters of the longitudinal ground stress profile and natural fracture comprise lithology, physical properties, rock mechanics, longitudinal ground stress profile, and natural fracture development characteristics.
8. the method of claim 6, wherein the factors controlling the fracture height and the support height comprise uncontrollable geological parameters and controllable fracture construction parameters.
9. The method of claim 8, wherein the uncontrollable geological parameters include longitudinal reservoir stress differential, longitudinal reservoir Young's modulus differential, and fracture toughness.
10. The method of claim 8, wherein the controllable fracture construction parameters include injection displacement, viscosity, and injection volume of each of the first, second, and third fracturing fluids, type of proppant, amount added, and sand concentration of construction sand added.
11. The method of claim 8, wherein a single factor sensitivity analysis is performed on the uncontrollable geological parameters and the controllable fracture construction parameters using fracture simulation software.
12. The method of claim 11, wherein the fracture simulation software is selected from at least one of FracPro, StimPlan, and GOHFER fracture simulation software.
13. The method according to any one of claims 1 to 5, wherein in step one, the acid and injection parameters are selected according to the reservoir conditions.
14. The method of claim 13, wherein the conditions of the reservoir comprise a mineral composition of the reservoir.
15. A process according to claim 13, wherein the acid solution comprises hydrochloric acid and/or earth acid.
16. the method of claim 13, wherein the injection parameters comprise a dosage of the acid solution.
17. A method according to claim 13, wherein the acid liquor is delivered at a rate of 0.5-1.3m3/min。
18. The method of any of claims 1-5, wherein the RPM pre-pad fracturing fluid of step two is a relative permeability modifier fracturing fluid.
19. The method of claim 18, wherein the amount of the relative permeability modifier fracturing fluid is determined based on simulation results from fracture simulation software.
20. The method of claim 18 wherein the RPM pre-pad has a make-up length of greater than 60% of the total make-up length of the fracture design.
21. The method according to any one of claims 1 to 5, wherein the construction time in the steps three, four and five is determined based on the simulation result of fracture simulation software.
22. The method of any of claims 1-5, wherein the weighted RPM fracturing fluid contains bromine salts and/or nitrate salts.
23. The method of any of claims 1-5, wherein the injection volume of the weighted RPM fracturing fluid is 1.0 to 1.1 times the amount of fracture volume below 2.0 to 3.0m at the bottom of the gas layer up to the bottom of the fracture of the water layer.
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| RU2801728C1 (en) * | 2022-12-23 | 2023-08-15 | Публичное акционерное общество "Татнефть" им. В.Д. Шашина | Hydraulic fracturing method |
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