CN108625839B - Formation fracturing method - Google Patents
Formation fracturing method Download PDFInfo
- Publication number
- CN108625839B CN108625839B CN201710158928.6A CN201710158928A CN108625839B CN 108625839 B CN108625839 B CN 108625839B CN 201710158928 A CN201710158928 A CN 201710158928A CN 108625839 B CN108625839 B CN 108625839B
- Authority
- CN
- China
- Prior art keywords
- fracturing
- pressure
- wellhead
- formation
- fracturing fluid
- 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.)
- Active
Links
- 230000015572 biosynthetic process Effects 0.000 title claims abstract description 40
- 238000000034 method Methods 0.000 title claims abstract description 29
- 238000010276 construction Methods 0.000 claims abstract description 17
- 230000002159 abnormal effect Effects 0.000 claims abstract description 7
- 239000012530 fluid Substances 0.000 claims description 45
- 239000011435 rock Substances 0.000 claims description 26
- 238000002347 injection Methods 0.000 claims description 16
- 239000007924 injection Substances 0.000 claims description 16
- 238000006073 displacement reaction Methods 0.000 claims description 15
- 230000035699 permeability Effects 0.000 claims description 13
- 238000005553 drilling Methods 0.000 claims description 12
- 238000011010 flushing procedure Methods 0.000 claims description 5
- 230000035485 pulse pressure Effects 0.000 claims description 4
- 230000009467 reduction Effects 0.000 claims description 4
- 238000005406 washing Methods 0.000 claims description 3
- 239000002253 acid Substances 0.000 claims description 2
- 239000002699 waste material Substances 0.000 abstract description 4
- 206010017076 Fracture Diseases 0.000 description 44
- 208000010392 Bone Fractures Diseases 0.000 description 35
- 238000012360 testing method Methods 0.000 description 12
- 238000011161 development Methods 0.000 description 8
- 239000007789 gas Substances 0.000 description 6
- 238000004519 manufacturing process Methods 0.000 description 4
- 239000002344 surface layer Substances 0.000 description 4
- 239000003795 chemical substances by application Substances 0.000 description 3
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 2
- 230000008859 change Effects 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 239000000203 mixture Substances 0.000 description 2
- 230000035515 penetration Effects 0.000 description 2
- 230000008569 process Effects 0.000 description 2
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 1
- 239000006004 Quartz sand Substances 0.000 description 1
- 230000005856 abnormality Effects 0.000 description 1
- 238000004458 analytical method Methods 0.000 description 1
- 230000002579 anti-swelling effect Effects 0.000 description 1
- 230000004888 barrier function Effects 0.000 description 1
- 125000005587 carbonate group Chemical group 0.000 description 1
- 238000005336 cracking Methods 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 239000004615 ingredient Substances 0.000 description 1
- 239000010410 layer Substances 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 239000012466 permeate Substances 0.000 description 1
- 239000003209 petroleum derivative Substances 0.000 description 1
- 235000021110 pickles Nutrition 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 238000003825 pressing Methods 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 230000000246 remedial effect Effects 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 238000010187 selection method Methods 0.000 description 1
- 238000004904 shortening Methods 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 239000002562 thickening agent Substances 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
Classifications
-
- 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
-
- 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
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
Landscapes
- Engineering & Computer Science (AREA)
- Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Mechanical Engineering (AREA)
- Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
Abstract
The invention relates to a formation fracturing method. The method comprises the following steps: determining a stratum parameter set before fracturing construction, and step two: and according to the abnormal parameters in the stratum parameter set, performing fracturing pretreatment firstly, and then performing normal fracturing construction. The stratum fracturing method can effectively realize stratum fracturing and reduce construction waste to the maximum extent.
Description
Technical Field
The invention relates to the field of petroleum and natural gas exploration and development, in particular to a formation fracturing method.
Background
During oil or gas production, after drilling, it is usually necessary to form fractures in the oil and gas reservoir by using water force. This process is known as fracturing and its purpose is to allow oil and gas to seep into the wellbore for production. For example, fracturing trucks are commonly used to squeeze liquids of a certain viscosity into a reservoir with high pressure. After a plurality of fractures are pressed in a reservoir (namely, a stratum is fractured), a propping agent (such as quartz sand and the like) is added to fill the fractures, so that the permeability of the oil-gas layer is improved, and the oil production is increased.
During fracturing operations, high formation fracture pressures are sometimes found. In this case, the injection rate of the fracturing fluid is low, the pressure at the wellhead is high, and there is no indication that the formation is fractured in the fracturing construction. For example, the injection displacement of the fracturing fluid is 0.2m3And the pressure of the well head reaches 90MPa in one minute. In such cases, it is difficult to add proppant to the fracturing fluid, which in turn fails to fracture or effectively propagate the formation.
In the prior art, the condition that the fracture pressure of the stratum is high cannot be effectively dealt with, and even the oil-gas well is abandoned, so that great waste is caused.
Disclosure of Invention
In order to solve the problems, the invention provides a formation fracturing method. The stratum fracturing method can effectively realize stratum fracturing and reduce construction waste to the maximum extent.
The stratum fracturing method comprises the following steps of: determining a stratum parameter set before fracturing construction, and step two: according to the abnormal parameters in the stratum parameter set, firstly carrying out fracturing pretreatment, and then carrying out normal fracturing construction.
According to the method of the present invention, prior to fracturing a drilled wellbore, formation parameters associated with fracturing of the wellbore are first determined. If one or more formation parameters are abnormal, for example, the abnormal parameters reflect conditions that may lead to fracture failure (e.g., formation fracture pressure is too high), a fracture pretreatment is first performed on the wellbore or formation to remove the abnormalities. Therefore, the method can effectively and favorably realize fracturing the stratum and reduce construction waste to the maximum extent.
In one embodiment, in step one, the well to be fractured is subjected to test fracturing, if the injection displacement of the test fracturing does not reach the maximum injection displacement, the abnormal parameters comprise the original perforation perfection, and the fracturing pretreatment is a remedial perforation operation. In particular, the injection displacement of a test fracture may be derived from the step-down displacement test results of the test fracture. Such testing methods are well known to those skilled in the art and will not be described in detail herein. The maximum injection displacement of the test fractures may be pre-designed based on previous exploration for the area, as is well known to those skilled in the art and will not be described further herein. Applicants have discovered that the size, density and depth of perforations produced by the original perforating operation may result in very high resistance of the fracturing fluid to the formation fractures, which in turn may result in conditions where the wellhead pressure is high during the test fracturing (and formal fracturing), but the injection rate of the fracturing fluid is low (i.e., the fracturing fracture of the formation is high). Under the condition, the operation of the injection hole can reduce the resistance of fracturing fluid entering the formation cracks caused by the injection hole problem, and further solve the problem of overhigh fracturing and fracturing of the formation.
In one embodiment, in a secondary perforation operation, a planar perforation pattern is used. Applicants have found that prior art helical perforations cause the formation to fracture and fracture to rise, especially for horizontal wells. Perforating using planar perforation patterns can reduce formation fracture fracturing by at least 30% compared to spiral perforation.
In one embodiment, the flat perforation is performed using a hydrajetting method. Applicants have found that the hydrajetting method achieves the goal of deep penetration perforation and, in contrast to conventional spiral perforation, the hydrajetting method produces a pore size increase of at least 40%. Accordingly, the hydrajetting method may help reduce fracture fracturing of the formation.
In one embodiment, in the hydrajetting method, two or more hydrajetting tools are used in series. By perforating in this manner, the deep penetration perforation of each jetting tool can be fully utilized. Furthermore, during the fracturing process, at least two of the multiple clusters of fractures created by perforating in this manner may be initiated and extended simultaneously, which helps to promote an increased level of fracture complexity. Thereby facilitating the subsequent oil recovery step.
In one embodiment, in a patch operation, a patch density is determined from the original perforation density and the original perforation perfection. For example, when the perforation perfection is below 60% and the original perforation density is 16 holes/meter, the patch density can be 10-12 holes/meter (i.e., 10-12 holes over a meter length). The patch density can be 6-8 holes/m when the perforation perfection is between 60% and 80% and the original perforation density is 16 holes/m. Under the condition of the hole patching density, the problem that the stratum fracture pressure is too high due to poor perforation perfection can be solved, and the strength of the casing pipe cannot be greatly reduced, so that the risk of deformation under high fracturing acting force is avoided.
In one embodiment, the anomaly parameter comprises permeability of the reservoir, and the fracture pretreatment is an operation of fracturing the rock using pulsed pressure when the permeability is less than a permeability criterion value. Applicants have found that in situations where the permeability of the formation rock is low, the fracturing fluid can build up in the well to create high bottom hole pressures, but the fracturing fluid is difficult to penetrate into the formation rock and cause difficulty in fracturing the formation. To this end, the applicant has creatively proposed applying a pulse pressure to the formation rock to cause fatigue cracking of the formation rock, which allows the fracturing fluid to penetrate into the formation rock and thereby reduce the formation fracture pressure. It should be understood that the permeability standard value can be obtained from various means such as rock type, well log data, core experiment, etc., which are well known to those skilled in the art and will not be described herein. For example, the formation rock is sandstone with a standard value of permeability of 0.1 md; the stratum rock is carbonate rock, and the standard value of the permeability of the stratum rock is 0.1 md.
In one embodiment, the operation of pulsed pressure fracturing rock comprises: step a, injecting fracturing fluid into a well to be subjected to fracturing construction until the pressure limit of a wellhead; step b, open-jetting the injected fracturing fluid from the wellhead until the pressure of the wellhead is reduced to a preset value; and repeating the steps a and b until the highest injection displacement of the fracturing fluid reaches a preset value. By repeatedly applying pressure and open-jetting the fracturing fluid to the stratum rock, a large amount of fatigue cracks can be generated on the stratum rock, and the fracturing fluid can smoothly permeate into the stratum rock, so that the stratum fracture pressure is reduced, and the stratum rock is fractured. It should be particularly noted that when the amount of fatigue fractures in the formation rock is such that the maximum injection rate of the fracturing fluid reaches a preset value, proppant may be added to the fracturing fluid and the subsequent fracturing step may be performed.
In one embodiment, in step b, the preset value of wellhead pressure is 0.
In one embodiment, in step b, the blowout flow rate of the fracturing fluid is gradually increased as the wellhead pressure is reduced. In a preferred embodiment, in step b, the blowout flow rate is continuously controlled by controlling the rate of decrease of the wellhead pressure P. Therefore, not only can stratum rocks generate a large amount of fatigue cracks, but also the degree of pressure change in the well can be effectively controlled, the situation that parts such as a packer arranged in the well are damaged due to too severe pressure change in the well is prevented, and meanwhile, the deformation of a shaft sleeve can be prevented. In a specific embodiment, in step b, when P is more than 30MPa, the descending speed of the wellhead pressure is 2 MPa/min; when P is more than 20MPa and less than or equal to 30MPa, the descending speed of the wellhead pressure is 3 MPa/min; when P is more than 0MPa and less than or equal to 20MPa, the descending speed of the wellhead pressure is 4 MPa/min. In one embodiment, the rate of wellhead pressure drop may be controlled by using different gauge blow-off nozzles.
In one embodiment, the anomaly parameter comprises a degree of natural surface fracture development of the reservoir, and when the degree of natural surface fracture development is good, the fracture pretreatment is to completely replace a first fracturing fluid of a first viscosity in the well with a second fracturing fluid having a second viscosity, the second viscosity being greater than the first viscosity. The development degree of the natural cracks on the surface layer can be known through well logging data or laboratory core tests, and whether the development degree of the natural cracks on the surface layer is good or not is judged according to the development degree of the natural cracks on the surface layer. For example, the propagation degree of the natural fracture can be judged according to the logging resistivity curve. Natural fracture development is better if the resistivity curve is decreased, and worse if not, as can be determined empirically by those skilled in the art. The applicant has found that in the case of a good development of natural fractures in the surface of the reservoir, the first fracturing fluid originally present in the well will preferentially enter the formation during fracturing. This results in that even if the second fracturing fluid is injected into the well at high displacement, it is difficult to form primary fractures in the formation rock, thereby making the width of each fracture low, resulting in formation fracture pressures that are too high and even ending the entire fracturing job. According to the method of the invention, the applicant uses the second fracturing fluid completely in place of the first fracturing fluid before the fracturing job. Thus, the second fracturing fluid with higher viscosity can fully penetrate into the formation rock cracks and form a main crack, and the natural surface cracks can hardly absorb the second fracturing fluid with higher viscosity in a large amount. Along with the enlargement of the size of the main crack, the capacity of the main crack for absorbing the second fracturing fluid is stronger and stronger, the capacity of the surface layer natural crack for absorbing the second fracturing fluid is gradually reduced, and finally, a mode of only feeding the main crack is formed. This will exhibit conventional formation fracture pressure. Therefore, the problem that the fracturing and fracturing of the stratum are too high is solved.
In one embodiment, the first fracturing fluid is completely displaced in a manner that shortens the time to increase the injection displacement of the second fracturing fluid to the maximum displacement. The applicant has found that rapidly increasing the injection rate of the second fracturing fluid can help to completely displace the first fracturing fluid with the second fracturing fluid. Thus, no other fluid is present in the well that competes with the second fracturing fluid for entry into the formation fracture, thereby solving the problem of too high a fracture in the formation.
In one embodiment, the viscosity of the second fracturing fluid and the reduced time to increase the injection displacement of the second fracturing fluid to the maximum displacement (hereinafter referred to as the reduced time) are determined based on the equivalent number of fractures and the integrated fluid loss coefficient. For example, for small scale tests, when the number of crack equivalent is more than 4 and the integrated fluid loss coefficient is 0.002m/min1/2In the above case, the second viscosity of the second fracturing fluid may be 200mpa.s or more, and the time after the shortening may be within 1 min. For small scale tests, the integrated fluid loss coefficient was 0.001m/min when the number of equivalent fracture pieces was 3 to 41/2To 0.002m/min1/2The second viscosity of the second fracturing fluid can be between 150mPa.s and 200mPa.s, and the shortened time is within 1.5 min. For small-scale tests, the number of equivalent pieces of the crack is 2 to 3, and the comprehensive fluid loss coefficient is 0.0008m/min1/2To 0.001m/min1/2Of a second fracturing fluidThe second viscosity can be between 100mPa.s and 150mPa.s, and the shortened time is within 2 min. In one embodiment, the composition of the second fracturing fluid may be: 0.2 percent of thickening agent, 0.3 percent of anti-swelling agent and 0.1 percent of discharge aiding agent by mass. These ingredients are well known to those skilled in the art.
In one embodiment, prior to step one, a circulating well-flushing operation is also performed. The applicant has found that during a fracturing operation, residual drilling mud in the well can build up under pressure at the perforations, and even if the formation breaks, the drilling mud will remain at the front of the fracturing fluid and act as a barrier to the fracturing fluid. These factors can also result in formation fracture pressures that are too high. According to the method of the invention, excess drilling mud in the well can be washed out of the well by a circulating flushing operation, so that the clogging effect of the drilling mud can be avoided. In a preferred embodiment, during drilling, if the drilling mud loss is greater than 10m3And/h, performing circulating well washing before the step one.
In one embodiment, a wash is used in a circulating well-flushing operation. The pickle liquor may react with the drilling mud and thereby further assist in washing out the drilling mud from the well. It will be appreciated that different acid wash solutions may be selected depending on the composition of the drilling mud, as the selection method is well known to those skilled in the art and will not be described in detail herein.
Compared with the prior art, the invention has the advantages that: the method can effectively improve the fracturing degree of the stratum, enhance the supply capacity of the fracture to the oil-gas seepage channel and furthest excavate the yield-increasing capacity of the reservoir.
Detailed Description
The invention will be further illustrated with reference to specific examples.
Example 1
The well S2 was cored and tested in the laboratory to see that the rock of the formation of interest was carbonate. The stratum fracture pressure gradient of the area is 0.021-0.029MPa/m, and the rock fracture pressure of the S2 well reaches about 85 MPa. The application scale of the fracturing technology in the oil field is restricted by the overhigh construction pressure, and the implementation of oil field production increasing measures is seriously influenced.
Through the analysis of the well early-stage data, the main reason for higher fracture pressure is that the permeability of reservoir rock is lower than the standard permeability value. Thus, the operation of fracturing rock by pulse pressure is adopted on the basis of conventional fracturing. In particular, in conventional fracturing (displacement of 4 m)3Min), stopping the pump, controlling the pressure of the well head to be 46.5MPa, selecting a 4mm oil nozzle for open flow, and controlling the pressure reduction speed of the well head to be 2 MPa/min. When the pressure of the well head is up to 30MPa to 20MPa, an oil nozzle with the specification of 5mm is selected for open flow, and the pressure reduction speed of the well head is 3 MPa/min. When the pressure of the well head is lower than 20MPa, an oil nozzle with the specification of 6mm is selected for open flow, and the pressure reduction speed of the well head is 4 MPa/min. When the pressure of the well head is reduced to 0, 5m is used3And injecting construction is carried out at the delivery volume per minute. In the subsequent fracturing construction, the fracture pressure of the S2 well is reduced to 76.2MPa, the designed sand adding amount is smoothly completed, and the fracturing construction is successful. Compared with the similar wells around, the highest construction pressure is reduced by about 8.8MPa after the pressure pulse measure is adopted.
While the invention has been described with reference to a preferred embodiment, various modifications may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In particular, the technical features mentioned in the embodiments can be combined in any way as long as there is no structural conflict. It is intended that the invention not be limited to the particular embodiments disclosed, but that the invention will include all embodiments falling within the scope of the appended claims.
Claims (7)
1. A formation fracturing method comprising the steps of,
the method comprises the following steps: determining a formation parameter set prior to fracturing construction, an
Step two: according to the abnormal parameters in the stratum parameter set, firstly carrying out fracturing pretreatment, then carrying out normal fracturing construction,
wherein the abnormal parameter comprises permeability of a reservoir, and when the permeability is smaller than a permeability standard value, the fracturing pretreatment is an operation of fracturing rock by using pulse pressure, wherein the operation of fracturing rock by using pulse pressure comprises the following steps:
step a, injecting fracturing fluid into a well to be subjected to fracturing construction until the pressure limit of a wellhead,
b, open-jetting the injected fracturing fluid from the wellhead until the pressure of the wellhead is reduced to a minimum pressure preset value, wherein the open-jetting flow rate of the fracturing fluid is gradually increased along with the reduction of the pressure of the wellhead,
and repeating the steps a and b until the highest injection displacement of the fracturing fluid reaches a preset value of the highest injection displacement.
2. A method according to claim 1, wherein in step b the blowout flow rate is continuously controlled by controlling the rate of decrease of the wellhead pressure P.
3. The method according to claim 2, wherein, in the step b,
when P is more than 30MPa, the descending speed of the wellhead pressure is 2 MPa/min;
when P is more than 20MPa and less than or equal to 30MPa, the descending speed of the wellhead pressure is 3 MPa/min;
when P is more than 0MPa and less than or equal to 20MPa, the descending speed of the wellhead pressure is 4 MPa/min.
4. The method according to any one of claims 1 to 3, wherein in step b, the minimum pressure preset value is 0.
5. A method according to any one of claims 1 to 3, wherein a circulating well-flushing operation is also carried out prior to step one.
6. The method of claim 5, wherein an acid wash is used in the circulating well-flushing operation.
7. The method of claim 5, wherein the first and second light sources are selected from the group consisting of,characterized in that during drilling, if the drilling mud leakage is more than 10m3And/h, performing circulating well washing before the step one.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201710158928.6A CN108625839B (en) | 2017-03-16 | 2017-03-16 | Formation fracturing method |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201710158928.6A CN108625839B (en) | 2017-03-16 | 2017-03-16 | Formation fracturing method |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN108625839A CN108625839A (en) | 2018-10-09 |
| CN108625839B true CN108625839B (en) | 2020-07-03 |
Family
ID=63687897
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201710158928.6A Active CN108625839B (en) | 2017-03-16 | 2017-03-16 | Formation fracturing method |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN108625839B (en) |
Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4858130A (en) * | 1987-08-10 | 1989-08-15 | The Board Of Trustees Of The Leland Stanford Junior University | Estimation of hydraulic fracture geometry from pumping pressure measurements |
| CN1361346A (en) * | 2000-12-29 | 2002-07-31 | 中国石油天然气股份有限公司 | Repeated pressure applying and releasing pulsed unblocking process |
| CN101446188A (en) * | 2008-12-30 | 2009-06-03 | 中国石油集团川庆钻探工程有限公司长庆井下技术作业公司 | Single upper seal sand blasting perforation fracturing technology |
| CN203191270U (en) * | 2013-04-25 | 2013-09-11 | 重庆地质矿产研究院 | Experimental device for pulse hydraulic fracturing reforms transform shale reservoir |
-
2017
- 2017-03-16 CN CN201710158928.6A patent/CN108625839B/en active Active
Patent Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4858130A (en) * | 1987-08-10 | 1989-08-15 | The Board Of Trustees Of The Leland Stanford Junior University | Estimation of hydraulic fracture geometry from pumping pressure measurements |
| CN1361346A (en) * | 2000-12-29 | 2002-07-31 | 中国石油天然气股份有限公司 | Repeated pressure applying and releasing pulsed unblocking process |
| CN101446188A (en) * | 2008-12-30 | 2009-06-03 | 中国石油集团川庆钻探工程有限公司长庆井下技术作业公司 | Single upper seal sand blasting perforation fracturing technology |
| CN203191270U (en) * | 2013-04-25 | 2013-09-11 | 重庆地质矿产研究院 | Experimental device for pulse hydraulic fracturing reforms transform shale reservoir |
Non-Patent Citations (1)
| Title |
|---|
| 降低压裂井底地层破裂压力的措施;黄禹忠;《断块油气田》;20150131;第12卷(第1期);74-78 * |
Also Published As
| Publication number | Publication date |
|---|---|
| CN108625839A (en) | 2018-10-09 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN110344799B (en) | Critical sand blocking fracturing method for improving complexity of cracks | |
| CN105507865B (en) | The method of refracturing for oil gas water well | |
| US20070007003A1 (en) | Formation treatment process | |
| CA2833992C (en) | Method of controlling a failed well with a ported packer | |
| CN107366530B (en) | Deep shale gas reservoir yield increasing method and application thereof | |
| CN107545088A (en) | A kind of normal pressure shale gas horizontal well volume fracturing method | |
| US20150152719A1 (en) | Enhanced Secondary Recovery of Oil and Gas in Tight Hydrocarbon Reservoirs | |
| CN111058817B (en) | Multi-section perforation fracturing horizontal well shaft integrity recovery method | |
| US5474129A (en) | Cavity induced stimulation of coal degasification wells using foam | |
| McNeil et al. | New hydraulic fracturing process enables far-field diversion in unconventional reservoirs | |
| RU2592582C1 (en) | Method of hydraulic fracturing | |
| CN108625838B (en) | Formation fracturing method | |
| CN108625839B (en) | Formation fracturing method | |
| US5199766A (en) | Cavity induced stimulation of coal degasification wells using solvents | |
| CN108625837B (en) | Formation fracturing method | |
| CN109209320B (en) | Secondary fracturing method for coal-bed gas well | |
| RU2452854C2 (en) | Method of directed hydraulic fracturing of reservoir | |
| CA2517497C (en) | Well product recovery process | |
| CN109252843B (en) | Oil and gas reservoir test fracturing method and oil and gas reservoir fracturing method | |
| Serdyuk et al. | Multistage Stimulation of Sidetrack Wellbores Utilizing Fiber-Enhanced Plugs Proves Efficient for Brown Oil Fields Development | |
| CN111364961A (en) | Super heavy oil SAGD exploitation method | |
| CN111396014B (en) | Thin interbed reservoir reformation method, device and equipment | |
| RU2285794C1 (en) | Well bottom zone treatment method | |
| CN109958427B (en) | Fracturing method for improving effective support profile | |
| CN113309502A (en) | Fracturing method for increasing transformation volume of deep shale gas reservoir |
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 |