CN114065529B - Shale gas repeated fracturing well section optimization method based on primary fracturing evaluation - Google Patents
Shale gas repeated fracturing well section optimization method based on primary fracturing evaluation Download PDFInfo
- Publication number
- CN114065529B CN114065529B CN202111374754.XA CN202111374754A CN114065529B CN 114065529 B CN114065529 B CN 114065529B CN 202111374754 A CN202111374754 A CN 202111374754A CN 114065529 B CN114065529 B CN 114065529B
- Authority
- CN
- China
- Prior art keywords
- fracturing
- primary
- section
- well section
- formula
- 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
Images
Classifications
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F30/00—Computer-aided design [CAD]
- G06F30/20—Design optimisation, verification or simulation
-
- 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
- E21B43/25—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
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F2119/00—Details relating to the type or aim of the analysis or the optimisation
- G06F2119/14—Force analysis or force optimisation, e.g. static or dynamic forces
Abstract
The invention discloses a shale gas repeated fracturing well section optimization method based on primary fracturing evaluation, which comprises the following steps: acquiring field primary fracturing parameters of each candidate well section; respectively carrying out normalization treatment on the primary fracturing construction pressure, the primary fracturing pump stopping pressure, the primary fracturing propping agent amount, the primary fracturing liquid amount, the primary fracturing construction displacement and the primary fracturing reservoir modification volume; carrying out numerical processing on the natural fracture development condition of each candidate well section; substituting the normalized values of all the parameters into the repeatable fracturing value index of each candidate well section; and (4) selecting the repeated fracturing well section according to the repeated fracturing value index. The influence of two factors, namely fracturing engineering parameters of the fracturing well and whether natural fractures of the reservoir develop or not, on the primary fracturing of the reservoir is fully considered, the repeated fracturing value of each candidate well section of the fracturing well is further judged, and the calculation of each parameter can be quickly calculated by using office software without nesting a complex model; is suitable for the rapid operation of field construction personnel.
Description
Technical Field
The invention relates to a shale gas repeated fracturing well section optimization method based on primary fracturing evaluation, and belongs to the technical field of unconventional oil and gas yield increase transformation.
Background
Shale gas refers to natural gas mainly located in dark shale or high-carbon shale and gathered together in an adsorption state or a free state, and is an important unconventional natural gas resource. Horizontal well fracturing is a core key technology for commercial development of shale gas, a concept of 'reservoir reforming volume (SRV)' is put forward for the first time in 2006 in the United states, a shale gas horizontal well segmented multi-cluster fracture network fracturing technology is gradually formed, and main shale gas production areas such as Barnett, Marcellulose and Haynesville are built. In the process of shale gas exploration and development in the early stage, limitations and deviations exist in the knowledge of a reservoir, so that the optimization design and process implementation of a fracturing well section are possibly not matched with the geological conditions of the reservoir, the reservoir is insufficiently transformed, the effect at the initial stage of fracturing is poor or the yield after fracturing is reduced rapidly; meanwhile, gas extraction is limited along with the loss of hydraulic fracture conductivity in the production process, and the final recovery ratio of the shale gas reservoir is reduced. The shale gas well repeated fracturing technology is used for remarkably reducing the yield of a gas well after primary fracturing, plugging by technologies such as chemical temporary plugging or mechanical packing when the yield is remarkably insufficient, performing secondary fracturing, and achieving the purposes of reconstructing a seam network, expanding a reconstruction area and improving the complexity of the seam network, so that the yield of the shale gas well is improved or recovered, and the ultimate recovery ratio of a reservoir is improved. At present, the mechanism research on shale gas repeated fracturing is still in a starting stage at home and abroad, and the weakness of the theoretical basis becomes a bottleneck restricting the process development, particularly the problems of shale gas horizontal well repeated fracturing well section optimization and the like.
At present, factors such as geological characteristics, reservoir characteristics, physical parameters, test production data and the like of a stratum are comprehensively considered by Song time weighting, and a repeated fracturing well selection and stratum selection method is formed; the Liuhuan et al propose that a shale gas reservoir with higher permeability is not a preferable interval for repeated fracturing, and an interval with high organic matter content is a preferable interval for repeated fracturing, which considers the influence of geological factors on repeated fracturing, and does not consider the influence of initial completion construction parameters and SRV on the repeated fracturing result. Harringhaman proposes a new method for rapidly screening potential horizontal fracturing candidate well sections by utilizing production performance and well completion data analysis; tavassoli et al propose that candidate wells can be selected through comprehensive numerical simulation studies that accurately model hydraulic fracturing and fracturing processes, but do not consider the effect of SRV on the re-fracturing results.
According to the defects in the existing research, the invention provides a repeated fracturing well section optimization method based on the evaluation of well completion parameters, reservoir transformation degree and natural fracture development conditions, establishes a repeated fracturing well section optimization standard based on a repeated fracturing index, and performs well section optimization application based on a mine field example well.
Disclosure of Invention
In order to overcome the problems in the prior art, the invention provides a shale gas repeated fracturing well section optimization method based on primary fracturing evaluation.
The technical scheme provided by the invention for solving the technical problems is as follows: a shale gas repeated fracturing well section optimization method based on primary fracturing evaluation comprises the following steps:
step one, acquiring field primary fracturing parameters of each candidate well section;
step two, carrying out normalization treatment on the primary fracturing construction pressure of each candidate well section;
step three, normalizing the primary fracturing pump-stopping pressure of each candidate well section;
step four, carrying out normalization treatment on the primary fracturing propping agent quantity of each candidate well section;
step five, performing normalization treatment on the primary fracturing fluid quantity of each candidate well section;
step six, performing normalization treatment on the primary fracturing construction discharge capacity of each candidate well section;
seventhly, performing normalization treatment on the primary fracturing reservoir reconstruction volume of each candidate well section;
step eight, carrying out numerical processing on the natural fracture development condition of each candidate well section to obtain the natural fracture development index of the candidate well section;
substituting the normalized values of all the parameters into the repeatable fracturing value index of each candidate well section;
in the formula: h i Is a repeatable fracture value index for each section;
normalizing the construction pressure of each section;
normalizing the value of the pump stopping pressure of each section;
normalizing the value of each section of the support dose;
normalizing the numerical value of each section of liquid volume;
normalizing the displacement value of each stage of primary fracturing construction;
transforming the volume normalized numerical value for each stage of the primary fracturing reservoir; q. q.s i The natural crack development index of each section;
and step ten, selecting the repeated fracturing well section according to the repeatable fracturing value index of each candidate well section.
The further technical scheme is that the normalization formula of the primary fracturing construction pressure is as follows:
in the formula:
normalizing the construction pressure of each section; p is a radical of fi Constructing pressure for each section; p is a radical of f(min) The minimum construction pressure in all well sections; p is a radical of f(max) The maximum construction pressure in all sections.
The further technical scheme is that the normalization formula of the pressure of the primary fracturing pump stopping is as follows:
in the formula:
normalizing the value of the pump stopping pressure of each section; p is a radical of si Stopping the pump pressure for each section; p is a radical of s(min) Minimum pump shut-off pressure in all intervals; p is a radical of s(max) The maximum pump-off pressure in all intervals.
The further technical scheme is that the normalization formula of the primary fracturing propping agent dosage is as follows:
in the formula:
normalizing the value of each section of the support dose; k i Supporting the dose for each segment; k (min) The minimum proppant amount in all well sections; k (max) The maximum proppant amount in all intervals.
The further technical scheme is that the normalization formula of the primary fracturing fluid volume is as follows:
in the formula:
normalizing the value of each segment of liquid volume; f i The liquid amount of each section; f (min) The minimum liquid volume in all well sections; f (max) The maximum amount of liquid in all intervals.
The further technical scheme is that the normalization formula of the primary fracturing construction displacement is as follows:
in the formula:
normalizing the displacement value of each stage of primary fracturing construction; d i Performing primary fracturing construction displacement for each section; d (min) The minimum construction displacement in all well sections is obtained; d (max) The maximum construction displacement in all well sections.
The further technical scheme is that the normalized formula of the primary fracturing reservoir reconstruction volume is as follows:
in the formula:
transforming the volume normalized numerical value for each stage of the primary fracturing reservoir; v i For each segment of SRV; v (min) The minimum SRV in all sections; v (max) The maximum SRV in all intervals.
The further technical scheme is that the specific process of the step eight is as follows: identifying the development condition of the natural fracture by combining the microseism event points and the MTI moment tensor inversion result with the shearing component larger than 0.8, analyzing a microseism event point distribution diagram and moment tensor inversion interpretation, carrying out numerical processing on the development condition of the actual natural fracture of the reservoir, and determining the natural fracture development index according to the following formula;
in the formula: q. q.s i The natural fracture development index of each segment is shown.
The further technical scheme is that the specific process of the tenth step is as follows: and determining the median of the repeatable fracturing index of each candidate well section according to the repeatable fracturing value index of each candidate well section, and selecting the well section with the repeatable fracturing index larger than the median as the repeatable fracturing well section.
The invention has the following beneficial effects: the method fully considers the influence of two factors, namely fracturing engineering parameters of the fracturing well and whether natural reservoir fractures develop or not, on the primary fracturing of the reservoir, and further judges the repeated fracturing value of each candidate well section of the fracturing well; the repeatable fracturing index calculation formula formed by analyzing the main factors influencing the artificial fracture development and the reservoir transformation rate is easy to use in practical engineering application, and the calculation of each parameter can be quickly calculated by using office software without nesting a complex model; is suitable for the rapid operation of field construction personnel.
Drawings
FIG. 1 is a block flow diagram of the present invention;
FIG. 2 illustrates a block A of microseismic event sites with seismic magnitude greater than-0.5 for the X-1 well in accordance with an embodiment of the present invention;
FIG. 3 is a graph of the inversion results of the MTI moment tensor for a block A with a X-1 well shear component greater than 0.8, in accordance with an embodiment of the present invention.
Detailed Description
The technical solutions of the present invention will be described clearly and completely with reference to the accompanying drawings, and it should be understood that the described embodiments are some, but not all embodiments of the present invention. All other embodiments, which can be obtained by a person skilled in the art without making any creative effort based on the embodiments in the present invention, belong to the protection scope of the present invention.
As shown in fig. 1, a shale gas repeated fracturing well section preferred method based on primary fracture evaluation of the present invention comprises the following steps:
the method comprises the steps of firstly, obtaining field primary fracturing parameters of each candidate well section, wherein the primary fracturing parameters comprise primary fracturing construction pressure, primary fracturing pump stopping pressure, primary fracturing propping agent amount, primary fracturing liquid amount and primary fracturing construction discharge amount;
step two, carrying out normalization treatment on the primary fracturing construction pressure of each candidate well section;
in the formula:
normalizing the construction pressure of each section; p is a radical of formula fi Constructing pressure for each section; p is a radical of f(min) The minimum construction pressure in all well sections; p is a radical of f(max) The maximum construction pressure in all well sections;
step three, normalizing the primary fracturing pump-stopping pressure of each candidate well section;
in the formula:
normalizing the value of the pump stopping pressure of each section; p is a radical of formula si Stopping the pump pressure for each section; p is a radical of s(min) The minimum pump-off pressure in all well sections; p is a radical of s(max) The maximum pump-off pressure in all well sections;
step four, performing normalization treatment on the primary fracturing propping agent quantity of each candidate well section;
in the formula:
normalizing the values for each segment of the support dose; k i Supporting the dose for each segment; k (min) The minimum proppant amount in all well sections; k (max) The maximum proppant amount in all sections;
step five, performing normalization processing on the primary fracturing fluid quantity of each candidate well section;
in the formula:
normalizing the value of each segment of liquid volume; f i The liquid amount of each section; f (min) The minimum liquid amount in all well sections; f (max) The maximum amount of liquid in all sections;
step six, performing normalization treatment on the primary fracturing construction discharge capacity of each candidate well section;
in the formula:
normalizing the displacement for each stage of primary fracturing construction; d i Performing primary fracturing construction displacement for each section; d (min) The minimum construction displacement in all well sections is obtained; d (max) The maximum construction displacement in all well sections is obtained;
step seven, performing normalization processing on the primary fracturing reservoir reconstruction volume of each candidate well section;
in the formula:
transforming the volume normalized numerical value for each stage of the primary fracturing reservoir; v i For each segment of SRV; v (min) The minimum SRV in all well sections; v (max) The maximum SRV in all sections;
step eight, carrying out numerical processing on the natural fracture development conditions of the candidate well sections to obtain natural fracture development indexes of the candidate well sections;
the more natural fractures develop, the greater the reservoir repeat fracturing potential. The development of natural fractures can be identified from the microseismic event points and the MTI moment tensor inversion results with shear components greater than 0.8. In the microseismic event point distribution diagram (as shown in fig. 2), different colors represent each well section, and a round ball nearby represents that a microseismic event occurs nearby the well section and has a natural fracture. Moment tensor inversion interpretation is based on microseismic event points with signal-to-noise ratio greater than 8, and for fracture angle analysis, event points with shear fracture ratio greater than 0.8 are mainly considered. The MTI moment tensor inversion result graph (as shown in FIG. 3) can represent a fracture opening event and a fracture closing event, the dislocation direction of the ice ball represents the fracture direction, and a natural fracture of a well section with fracture opening dislocation nearby develops. The method combines the development condition of actual natural fractures of a reservoir with field experience to carry out numerical treatment through a formula 7;
in the formula: q. q.s i The natural crack development index of each section;
substituting the normalized values of all the parameters into the repeatable fracturing value index of each candidate well section;
in the formula: h i Is a repeatable fracture value index for each section;
normalizing the construction pressure of each section;
normalizing the value of the pump stopping pressure of each section;
normalizing the values for each segment of the support dose;
normalizing the value of each segment of liquid volume;
normalizing the displacement value of each stage of primary fracturing construction;
transforming the volume normalized numerical value for each stage of the primary fracturing reservoir; q. q.s i The natural crack development index of each section;
step ten, selecting a repeated fracturing well section according to the repeatable fracturing value index of each candidate well section;
finding out the median of the repeatable fracture index of each candidate well section of the repeated fracturing well through software such as EXCEL and MATLAB, and selecting the well section with the repeatable fracture index larger than the median as the repeated fracturing well section.
Examples
The embodiment provides a preferable method for repeatedly fracturing a well section of a rock gas reservoir based on primary fracture evaluation, which comprises the following steps:
step 1, acquiring primary fracturing data of an X-1 well of a block A, and referring to a table 1;
TABLE 1X-1 well Primary fracturing data
Step 2, respectively carrying out normalization treatment on the primary fracturing construction pressure, the primary fracturing pump stopping pressure, the primary fracturing propping agent amount, the primary fracturing liquid amount, the primary fracturing construction discharge amount and the primary fracturing reservoir modification volume according to the formulas (1) to (7); the results of the above normalization processing are shown in Table 2;
TABLE 2 normalization of the results
Step 3, identifying the development condition of the natural fractures by combining the microseism event points and MTI moment tensor inversion results with shearing components larger than 0.8, analyzing a microseism event point distribution diagram and moment tensor inversion interpretation, and carrying out numerical processing on the development condition of the actual natural fractures of the reservoir, wherein the obtained natural fracture development index is shown in a table 3;
TABLE 3 numeralization of natural fracture development for each interval of the X-1 well
| Natural fracture growth index q i | 1 | 0.6 | 0.2 |
| Well section | 4～8、13～17、19～21 | 3、12 | 1、2、9～11、18 |
And 4, substituting the parameters into the repeatable fracturing index calculation and display to obtain the repeatable fracturing index of the candidate well section, wherein the repeatable fracturing index of each well section is shown in a table 4.
TABLE 4 repeatable fracturing index for each well section of X-1 well
And 5, finding out that the median of the repeatable fracturing index is 0.643, and selecting the well section with the repeatable fracturing index larger than the median as a repeated fracturing well section, namely, 10 sections of 1-4, 6-8, 16, 20 and 21 sections in the X-1 well have higher scores and can be used as the repeated fracturing well section.
Although the present invention has been described with reference to the above embodiments, it should be understood that the present invention is not limited to the above embodiments, and those skilled in the art can make various changes and modifications without departing from the scope of the present invention.
Claims (9)
1. A shale gas repeated fracturing well section optimization method based on primary fracturing evaluation is characterized by comprising the following steps:
step one, acquiring field primary fracturing parameters of each candidate well section;
step two, carrying out normalization treatment on the primary fracturing construction pressure of each candidate well section;
step three, normalizing the primary fracturing pump-stopping pressure of each candidate well section;
step four, carrying out normalization treatment on the primary fracturing propping agent quantity of each candidate well section;
step five, performing normalization treatment on the primary fracturing fluid quantity of each candidate well section;
step six, performing normalization treatment on the primary fracturing construction discharge capacity of each candidate well section;
seventhly, performing normalization treatment on the primary fracturing reservoir reconstruction volume of each candidate well section;
step eight, carrying out numerical processing on the natural fracture development condition of each candidate well section to obtain the natural fracture development index of the candidate well section;
substituting the normalized values of all the parameters into the repeatable fracturing value index of each candidate well section;
in the formula: h i Is a repeatable fracture value index for each section;
normalizing the construction pressure of each section;
normalizing the value of the pump stopping pressure of each section;
normalizing the values for each segment of the support dose; f i * Normalizing the numerical value of each section of liquid volume;
normalizing the displacement value of each stage of primary fracturing construction; v i * Transforming the volume normalized numerical value for each stage of the primary fracturing reservoir; q. q.s i The natural crack development index of each section;
and step ten, selecting the repeated fracturing well section according to the repeatable fracturing value index of each candidate well section.
2. The shale gas repeated fracturing interval optimization method based on initial fracturing evaluation as claimed in claim 1, wherein the normalized formula of the initial fracturing construction pressure is:
in the formula:
normalizing the construction pressure of each section; p is a radical of fi Constructing pressure for each section; p is a radical of f(min) The minimum construction pressure in all well sections is used; p is a radical of f(max) The maximum construction pressure in all sections.
3. The shale gas repeated fracturing interval optimization method based on initial fracturing evaluation as claimed in claim 1, wherein the normalized formula of the initial fracturing pump-down pressure is:
in the formula:
normalizing the value of the pump stopping pressure of each section; p is a radical of formula si Stopping the pump pressure for each section; p is a radical of s(min) The minimum pump-off pressure in all well sections; p is a radical of formula s(max) The maximum pump-off pressure in all intervals.
4. The primary fracture evaluation based shale gas frac interval optimization method of claim 1, wherein the normalization formula of the primary fracture proppant volume is:
in the formula:
normalizing the values for each segment of the support dose; k i Supporting the dose for each segment; k (min) The minimum proppant amount in all well sections; k (max) The maximum proppant volume in all intervals.
5. The shale gas repeated fracturing interval preferred method based on primary fracture evaluation as claimed in claim 1, wherein the normalized formula of the primary fracture liquid amount is:
in the formula: f i * Normalizing the value of each segment of liquid volume; f i The liquid amount of each section; f (min) The minimum liquid volume in all well sections; f (max) The maximum amount of liquid in all intervals.
6. The shale gas repeated fracturing interval optimization method based on initial fracturing evaluation as claimed in claim 1, wherein the normalized formula of the initial fracturing construction displacement is as follows:
in the formula:
normalizing the displacement value of each stage of primary fracturing construction; d i Discharging volume for each stage of primary fracturing construction; d (min) The minimum construction displacement in all well sections is obtained; d (max) The maximum construction displacement in all well sections.
7. The primary fracture evaluation based shale gas re-fracturing interval optimization method as claimed in claim 1, wherein the normalized formula of the primary fracture reservoir reformation volume is:
in the formula: v i * Transforming the volume normalized numerical value for each stage of the primary fracturing reservoir; v i For each segment of SRV; v (min) The minimum SRV in all sections; v (max) The maximum SRV in all intervals.
8. The shale gas repeated fracturing interval optimization method based on primary fracturing evaluation as claimed in claim 1, wherein the specific process of step eight is: identifying the development condition of the natural fracture by combining the microseism event points and the MTI moment tensor inversion result with the shearing component larger than 0.8, analyzing a microseism event point distribution diagram and moment tensor inversion interpretation, carrying out numerical processing on the development condition of the actual natural fracture of the reservoir, and determining the natural fracture development index according to the following formula;
in the formula: q. q.s i The natural fracture development index of each segment is shown.
9. The shale gas repeated fracturing interval optimization method based on primary fracturing evaluation as claimed in claim 1, wherein the detailed process of the step ten is as follows: and determining the median of the repeatable fracturing index of each candidate well section according to the repeatable fracturing value index of each candidate well section, and selecting the well section with the repeatable fracturing index larger than the median as the repeatable fracturing well section.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202111374754.XA CN114065529B (en) | 2021-11-17 | 2021-11-17 | Shale gas repeated fracturing well section optimization method based on primary fracturing evaluation |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202111374754.XA CN114065529B (en) | 2021-11-17 | 2021-11-17 | Shale gas repeated fracturing well section optimization method based on primary fracturing evaluation |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN114065529A CN114065529A (en) | 2022-02-18 |
| CN114065529B true CN114065529B (en) | 2022-08-23 |
Family
ID=80278468
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202111374754.XA Active CN114065529B (en) | 2021-11-17 | 2021-11-17 | Shale gas repeated fracturing well section optimization method based on primary fracturing evaluation |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN114065529B (en) |
Family Cites Families (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN106845043A (en) * | 2017-04-07 | 2017-06-13 | 东方宝麟科技发展(北京)有限公司 | A kind of technological process of shale gas horizontal well refracturing and method for designing |
| CN107387051B (en) * | 2017-09-05 | 2020-03-27 | 西南石油大学 | Repeated fracturing well selection method for multi-stage fractured horizontal well with low-permeability heterogeneous oil reservoir |
| CN107705215B (en) * | 2017-09-25 | 2018-07-27 | 西南石油大学 | A kind of shale reservoir refracturing selects well selections method |
| CN107587867B (en) * | 2017-09-25 | 2018-06-12 | 西南石油大学 | A kind of refracturing process design method for promoting shale seam net complexity |
-
2021
- 2021-11-17 CN CN202111374754.XA patent/CN114065529B/en active Active
Also Published As
| Publication number | Publication date |
|---|---|
| CN114065529A (en) | 2022-02-18 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN107044277B (en) | Low permeable and heterogeneity reservoir horizontal well refracturing yield potential evaluation method | |
| CN106909758B (en) | A kind of method of fine and close oily reservoir-level well multistage sub-clustering perforating site optimization design | |
| CN109594968A (en) | Fracture parameters evaluation method and system after a kind of shale gas multistage pressure break horizontal well pressure | |
| CN107387051B (en) | Repeated fracturing well selection method for multi-stage fractured horizontal well with low-permeability heterogeneous oil reservoir | |
| CN109815516A (en) | The method and device that shale gas well deliverability is predicted | |
| Laochamroonvorapongse et al. | Performance assessment of miscible and immiscible water-alternating gas floods with simple tools | |
| CN106869911A (en) | A kind of evaluation method for describing shale reservoir compressibility | |
| Xu et al. | Field test of volume fracturing for horizontal wells in Sulige tight sandstone gas reservoirs, NW China | |
| CN111927417A (en) | Shale gas staged fracturing horizontal well group reserve utilization condition evaluation method | |
| US11598205B1 (en) | Method for comprehensive evaluation of shale fracability under the geology-engineering “double-track” system | |
| CN110094196A (en) | A kind of carbonate rock open-hole horizontal well segmentation acid fracturing effect evaluation method | |
| Bin et al. | Intelligent identification and real-time warning method of diverse complex events in horizontal well fracturing | |
| CN109190218B (en) | Dynamic identification method for effective seam net of tight reservoir | |
| CN114091287B (en) | Method for evaluating crack connectivity and optimizing crack parameters based on complex network theory | |
| CN116122801A (en) | Shale oil horizontal well volume fracturing compressibility comprehensive evaluation method | |
| CN110390154A (en) | A method of improving Complex reservoir reservoir numerical simulation efficiency | |
| Sun et al. | A new numerical well test method of multi-scale discrete fractured tight sandstone gas reservoirs and its application in the Kelasu Gas Field of the Tarim Basin | |
| CN116128083A (en) | Quantitative characterization method for volume of shale oil horizontal well volume fracturing crack | |
| CN109426689B (en) | Evaluation method and system for horizontal well fracturing fracture | |
| CN112068198B (en) | Crack fracture dimension description method based on seismic wave full waveform characteristics | |
| CN114065529B (en) | Shale gas repeated fracturing well section optimization method based on primary fracturing evaluation | |
| CN115809536A (en) | Evaluation method for multi-section fracturing reformation of shale gas well | |
| CN111650640B (en) | Crack network complexity evaluation method and system | |
| CN116362121A (en) | Method and device for determining crack parameters of horizontal well fracturing | |
| CN106845685B (en) | Parameter optimization method for reducing horizontal well oil testing fracturing operation cost |
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 |