CN111963149B - Post-fracturing stratum pressure solving method taking earth stagnation amount pressurization into consideration - Google Patents
Post-fracturing stratum pressure solving method taking earth stagnation amount pressurization into consideration Download PDFInfo
- Publication number
- CN111963149B CN111963149B CN202010872835.1A CN202010872835A CN111963149B CN 111963149 B CN111963149 B CN 111963149B CN 202010872835 A CN202010872835 A CN 202010872835A CN 111963149 B CN111963149 B CN 111963149B
- Authority
- CN
- China
- Prior art keywords
- pressure
- fracturing
- formation pressure
- formation
- pressurization
- 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
- 238000000034 method Methods 0.000 title claims abstract description 42
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 91
- 239000007788 liquid Substances 0.000 claims abstract description 29
- 238000009792 diffusion process Methods 0.000 claims abstract description 28
- 230000008859 change Effects 0.000 claims abstract description 22
- 238000010276 construction Methods 0.000 claims abstract description 20
- 230000008569 process Effects 0.000 claims abstract description 10
- 230000003247 decreasing effect Effects 0.000 claims abstract description 8
- 206010016807 Fluid retention Diseases 0.000 claims description 14
- 239000012530 fluid Substances 0.000 claims description 13
- 238000006073 displacement reaction Methods 0.000 claims description 7
- 230000035699 permeability Effects 0.000 claims description 6
- 238000012360 testing method Methods 0.000 claims description 5
- 239000004927 clay Substances 0.000 claims description 3
- 238000012937 correction Methods 0.000 claims description 3
- 239000011159 matrix material Substances 0.000 claims description 3
- 238000011156 evaluation Methods 0.000 abstract description 4
- 238000004364 calculation method Methods 0.000 description 10
- 238000004088 simulation Methods 0.000 description 8
- 238000002791 soaking Methods 0.000 description 5
- 230000008901 benefit Effects 0.000 description 4
- 230000000694 effects Effects 0.000 description 3
- 238000004519 manufacturing process Methods 0.000 description 3
- 239000003795 chemical substances by application Substances 0.000 description 2
- 230000007423 decrease Effects 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 238000011158 quantitative evaluation Methods 0.000 description 2
- 238000006467 substitution reaction Methods 0.000 description 2
- 238000004458 analytical method Methods 0.000 description 1
- 230000001174 ascending effect Effects 0.000 description 1
- 230000002238 attenuated effect Effects 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000000704 physical effect Effects 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 230000004044 response Effects 0.000 description 1
- 230000036962 time dependent Effects 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
-
- 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
-
- 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
Abstract
The invention discloses a method for solving formation pressure after fracturing by considering earth stagnation amount pressurization, which comprises the following steps: inputting geological parameters, engineering parameters and fracturing construction parameters of a target reservoir into a fracturing crack expansion model, simulating to obtain stratum pressure change of the target reservoir in the fracturing construction process, selecting stratum pressure when the ground entering liquid amount is the same as the ground stagnation liquid amount of the target reservoir, and taking the stratum pressure as initial stratum pressure under the influence of the ground stagnation liquid amount pressurization; inputting the initial formation pressure into a pressure diffusion model to obtain a decreasing change rule of the formation pressure along with time after fracturing, and further obtaining the formation pressure at any moment according to the decreasing change rule of the formation pressure along with time. By the method, dynamic evaluation of near-well stratum pressure after fracturing is realized.
Description
Technical Field
The invention belongs to the field of oil and gas reservoir engineering, in particular to calculation of formation pressure in a flowback production period after fracturing, and mainly considers the influence of fluid-to-ground pressure boost and pressure diffusion to the far end of a formation on the formation pressure.
Background
With the continuous decline of the grade of newly increased oil gas exploration reserves in China, the benefits of oil gas development are restricted by a plurality of low-yield wells. Meanwhile, the horizontal well and volume fracturing technology at home and abroad is rapidly developed, and remarkable application results are obtained in low-permeability and unconventional oil and gas reservoir development. However, reservoirs with different types and physical properties have larger difference in formation productivity under the condition of adopting different fracturing construction scales and modes, wherein the size and the change of formation pressure after fracturing have remarkable influence on the formation productivity, but the formation pressure obtaining means after fracturing are limited at present. Therefore, a method for obtaining the formation pressure after fracturing by taking the earth stagnation amount into consideration is needed.
Disclosure of Invention
Aiming at the problems that the formation pressure after fracturing changes, the influence factors are many, the rule is complex, the means for continuously acquiring the dynamic formation pressure is lacking, and the like, the invention provides the method for solving the formation pressure after fracturing, which considers the pressurization of the fluid-retention amount, and the method is used for dynamically evaluating the formation pressure near the well after fracturing.
In order to solve the technical problems, the invention is realized by the following technical scheme:
a method for calculating formation pressure after fracturing taking into account fluid-retention volume pressurization, comprising:
inputting geological parameters, engineering parameters and fracturing construction parameters of a target reservoir into a fracturing crack expansion model, simulating to obtain stratum pressure change of the target reservoir in the fracturing construction process, selecting stratum pressure when the ground entering liquid amount is the same as the ground stagnation liquid amount of the target reservoir, and taking the stratum pressure as initial stratum pressure under the influence of the ground stagnation liquid amount pressurization;
inputting the initial formation pressure into a pressure diffusion model to obtain a decreasing change rule of the formation pressure along with time after fracturing, and further obtaining the formation pressure at any moment according to the decreasing change rule of the formation pressure along with time.
Further, the crack propagation model is a PKN model of a multi-slit mode, and the expression of the PKN model of the multi-slit mode is:
wherein:
wherein: w (W) max (x) The maximum slit width of the point x in the slit under the laminar flow condition of Newton liquid is m;
p (x) is the pressure of the point x in the crack, pa; pc is crack closing pressure, pa;
mu is the viscosity of the fracturing fluid in the fracture and Pa.s; e is Young's modulus, pa; v is poisson's ratio, dimensionless;
alpha is a coefficient related to displacement, and is dimensionless; h is the crack height, m; l is half length of the split seam, m;
q is displacement, m 3 A/min; a is the area of the crack, m 2 ；D f Fractal dimension of fracture plane, dimensionless；
C is the integrated fluid loss coefficient,
erfc (x) is the error compensation function of x.
Further, the expression of the pressure diffusion model is:
P(t)＝P e +(P b0 -P e )e -at
wherein: p (t) is the dynamic formation pressure after fracturing; p (P) e Is the original formation pressure; p (P) b0 The method comprises the steps of (1) setting an initial pressure of a near-well stratum under the influence of the pressurization of a ground stagnation liquid; a is the pressure diffusion rate index; t is time.
Further, the geological parameters include: depth in the middle of the reservoir, reservoir thickness, clay content, porosity, permeability, and oil (gas) saturation.
Further, the engineering parameters include: formation pressure, young's modulus, poisson's ratio, biot coefficient, vertical principal stress, maximum horizontal principal stress, and minimum horizontal principal stress.
Further, the fracturing construction parameters include: average displacement, fracturing time, fracturing fluid viscosity, fluid loss factor, total proppant and fluid retention.
Further, the diffusion coefficient in the pressure diffusion model is determined by the fracture sum volume and the reservoir matrix permeability.
And further, performing scale correction on the diffusion coefficient in the pressure diffusion model by using pressure test data of actual fracturing construction.
Compared with the prior art, the invention has at least the following beneficial effects: the existing method for acquiring the formation pressure after fracturing mainly comprises the steps of calculating through fracturing construction data, closing a well after fracturing and measuring wellhead pressure change, and calculating the formation pressure through wellhead pressure and shaft liquid column pressure. Compared with such techniques, the present invention has at least three advantages: 1. formation pressure may be calculated in wells for which post-pressure drop tests have not been made; 2. the dynamic change condition of the stratum pressure can be simulated and calculated; 3. meanwhile, the change of the distribution of the fluid-stagnating amount is considered, so that the formation pressure change of the formation in different radial depths can be obtained theoretically. According to the method, formation pressure information corresponding to the fluid retention amount at the end of flowback is obtained by simulating formation pressure change information obtained by crack propagation, so that a near-well formation pressure attenuation model (namely a pressure diffusion model) generated by diffusion of the fluid retention to the formation is introduced, dynamic calculation of the near-well formation pressure after the flowback is finished is realized, the relative error of a calculation result in the formation in a specific area can be controlled below 1%, the problem that the near-well formation pressure is difficult to continuously calculate after fracturing, particularly after flowback, is solved, and basic parameters are provided for dynamic productivity prediction.
In order to make the above objects, features and advantages of the present invention more comprehensible, preferred embodiments accompanied with figures are described in detail below.
Drawings
In order to more clearly illustrate the technical solutions of the embodiments of the present invention, the drawings that are needed in the description of the embodiments will be briefly described below, and it is obvious that the drawings in the following description are some embodiments of the present invention, and other drawings may be obtained according to these drawings without inventive effort for a person skilled in the art.
FIG. 1 is a schematic diagram of a formation pressure calculation method taking into account fluid-retention pressurization in accordance with the present invention;
FIG. 2 is a schematic illustration of the parameter input of the multi-slit mode based PKN model of the present invention;
fig. 3 is a schematic diagram of a simulation calculation of the fracturing pumping-in period near-well formation pressure of the multi-slit mode-based PKN model.
Detailed Description
For the purpose of making the objects, technical solutions and advantages of the embodiments of the present invention more apparent, the technical solutions of the present invention will be clearly and completely described below with reference to the accompanying drawings, and it is apparent that the described embodiments are some embodiments of the present invention, but not all embodiments. All other embodiments, which can be made by those skilled in the art based on the embodiments of the invention without making any inventive effort, are intended to be within the scope of the invention.
The logging data can provide relatively economical and continuous quantitative evaluation results for reservoir geological parameters and engineering parameter evaluation, and can also be used for carrying out fracture propagation simulation based on the quantitative evaluation results, and in a 2D fracture propagation model (such as a PKN model in a multi-fracture mode) which can be solved in a part of analysis, the formation pressure in the fracturing process can be solved through the model. This provides the possibility to find the formation pressure with known earth stagnation in the production stage of flowback after fracturing.
The invention aims to solve the problem of formation pressure calculation affecting formation productivity after fracturing. The invention provides a method for solving initial stratum pressure after fracturing by considering the pressurization effect of the earth-stagnation liquid, which utilizes logging response data to evaluate reservoir geology and engineering parameters, further carries out fracture expansion simulation, simulates the fracturing construction process until the earth-stagnation liquid reaches the acquired earth-stagnation liquid, considers the stratum pressure obtained by simulation calculation to be similar to the stratum pressure caused by the pressurization of the earth-stagnation liquid, further carries out attenuation correction of the stratum pressure along with time, and utilizes the whole model of actual data scale to realize stratum pressure prediction under the condition of known earth-stagnation liquid in the production period of fracturing flowback.
As one embodiment of the present invention, a method for determining post-fracture formation pressure taking into account fluid-retention pressurization, includes:
firstly, inputting geological parameters, engineering parameters and fracturing construction parameters of a target reservoir into a fracturing crack expansion model, simulating to obtain formation pressure changes of the target reservoir in the fracturing construction process (such as curve a in fig. 1, wherein the curve a comprises a fracturing and a change indication of near-well formation pressure in a later well closing state, an ascending section is near-well formation pressure changes in a pumping stage, a descending section is formation pressure attenuation in a post-pressure pump stopping stage), and simulating to obtain formation pressure when the length and width of a crack of the target reservoir are the same as the size of a fluid stagnation of the target reservoir in the fracturing construction process, wherein the formation pressure is used as an initial formation pressure under the influence of fluid stagnation pressurization; that is, the fracturing construction process is simulated until the ground entering liquid amount is the same as the ground stagnation liquid amount of the target reservoir, and the formation pressure obtained by simulation calculation is considered to be similar to the formation pressure caused by pressurization of the ground stagnation liquid amount (containing the propping agent volume) (the same fracturing liquid amount is contained in the formation);
in this embodiment, the geological parameters and engineering parameters of the target reservoir are calculated based on the logging data, and specifically, the geological parameters include: depth of middle reservoir, reservoir thickness, clay content, porosity, permeability, and oil (gas) saturation; the engineering parameters include: formation pressure, young's modulus, poisson's ratio, biot coefficient, vertical principal stress, maximum horizontal principal stress, and minimum horizontal principal stress;
in this embodiment, the fracturing construction parameters include: average displacement, fracturing time, fracturing fluid viscosity, fluid loss coefficient, total proppant and fluid retention;
in this embodiment, the fracture propagation model is a PKN model in a multi-slit mode, and the expression of the PKN model in the multi-slit mode is:
for the seam length parameter, a Kate model seam surface area formula is generally introduced during solving, and the solving is realized through iteration, wherein the formula is as follows:
L＝A/2H
or, in the solving process of the fracture propagation model, considering the general condition in fracturing of the tight reservoir, namely considering that the fracture exists in a seam network form with certain complexity, improving the solving method, and introducing a seam network plane fractal dimension D f And (3) making:
d is taken according to fractal dimension value of general complex plane figure f Taking 1.12 to 1.18;
wherein: w (W) max (x) The maximum slit width of the point x in the slit under the laminar flow condition of Newton liquid is m;
p (x) is the pressure of the point x in the crack, pa; pc is crack closing pressure, pa;
mu is the viscosity of the fracturing fluid in the fracture and Pa.s; e is Young's modulus, pa; v is poisson's ratio, dimensionless;
alpha is a coefficient related to displacement, and is dimensionless; h is the crack height, m; l is half length of the split seam, m;
q is displacement, m 3 A/min; a is the area of the crack, m 2 ；D f Fractal dimension is a fracture plane, and dimensionless;
c is the integrated fluid loss coefficient,
erfc (x) is the error compensation function of x.
Then, inputting the initial formation pressure into a pressure diffusion model to obtain a decreasing change rule of the formation pressure with time after fracturing (curve b in fig. 1, curve b is the change of the formation pressure near the well after flowback is finished), and further obtaining the formation pressure at any moment according to the decreasing change rule of the formation pressure with time; the diffusion coefficient in the pressure diffusion model is obtained through fracturing waves and volume and reservoir matrix permeability;
in this embodiment, the expression of the pressure diffusion model is:
P(t)＝P e +(P b0 -P e )e -at
wherein: p (t) is fracturingPost-dynamic formation pressure; p (P) e Is the original formation pressure; p (t) is the dynamic formation pressure after fracturing; p (P) e Is the original formation pressure; p (P) b0 The method comprises the steps of (1) setting an initial pressure of a near-well stratum under the influence of the pressurization of a ground stagnation liquid; a is the pressure diffusion rate index; t is time;
in the embodiment, based on the maximum half length of the fracture and the horizontal stress difference, estimating the fracture swept volume (SRV) according to an elliptic cylinder model;
in the present embodiment, in a region where some data are sufficient, the diffusion coefficient in the pressure diffusion model is corrected by using the measured data obtained by the fracturing operation (i.e., the pressure test data of the actual fracturing operation), by the calibration method in which the time (unit: hours) when the measured formation pressure attenuation width reaches 95% is obtained, and the following empirical formula a=0.777·t is used -1.05 And giving an a value, and improving the calculation accuracy of the model in other wells and other reservoirs in the region.
Curve c in fig. 1 is the pressure change during the post-press flowback phase; in fig. 1, the time axis is a relative dimension.
The principle of the invention is as follows: the invention relates to a near-well stratum pressure simulation solving method which is adopted for obtaining near-well stratum pressure under specific fluid-stagnation after fracturing and flowback of a tight reservoir. Firstly, realizing fracture expansion simulation work based on logging reservoir parameters and fracturing construction parameters so as to acquire formation pressures corresponding to different amounts of in-situ fluid during fracturing, wherein the formation pressures are described in detail above; secondly, adopting an equivalent mode, and considering that when the earth-entering liquid amount is the same as the earth-stagnation liquid amount, the near-well stratum pressure is equal, thereby obtaining the near-well stratum pressure P at the end of flowback b0 The method comprises the steps of carrying out a first treatment on the surface of the Furthermore, the near-well fracturing fluid is considered to be continuously expanded towards the stratum during the well soaking, the near-well stratum pressure is gradually attenuated until the near-well stratum pressure is consistent with the original stratum pressure, and the near-well stratum pressure attenuation amplitude and the near-well stratum pressure value P (t) of the corresponding time during the well soaking are obtained by utilizing a pressure diffusion model formula according to the time of well soaking (well closing after flowback); finally, a near-well formation pressure sequence is predicted. And in the meantime, the pressure diffusion model is scaled by actual data so as to improve the formation pressure obtaining precision.
Examples:
taking a certain well of XX stratum in LJZ area of CQ oil field as an example, the method comprises the following steps:
step 1) carrying out fracture propagation simulation based on a PKN model of an improved multi-joint mode according to reservoir and engineering parameters (shown in figure 2) of logging evaluation and with the combination of fracture construction parameters, and acquiring formation pressure, maximum half-joint length and maximum joint width information (shown in figure 3) corresponding to different earth-entering liquid amounts in the fracturing process;
step 2) the amount of the stagnant liquid after the combination of the flowback is 50m 3 According to FIG. 3, the amount of the available ground liquid is 50m 3 The near-well stratum pressure is 29.00Mpa at the time of the end of flowback and is used as the initial stratum pressure P after near-well fracturing b0 ；
Step 3) combining the original stratum pressure P according to the time of well soaking (closing after flowback) for 50h e 27.15Mpa and a regional experience a of 0.045, and obtaining a near-well stratum pressure attenuation amplitude during well soaking and a near-well fracturing dynamic stratum pressure value P (t) of 27.35Mpa at corresponding time by using a formula 6;
the measured pressure of the wellhead after the well is shut in is 3.75Mpa, and the density of the well bore fluid is 1.13g/cm 3 The stratum depth is 2125m, the back calculation near well stratum pressure is 23.60Mpa, and the error is 0.28%.
The invention discloses a method for solving formation pressure in an initial stage after fracturing by considering the earth stagnation amount pressurizing effect, and belongs to the field of evaluation of oil and gas-containing reservoirs. Based on a simulated fracture propagation model, the method comprehensively obtains the formation pressure and the change condition thereof after the fracturing fluid flowback by assuming that the near-well formation pressure is similar when the same volume of external fluid (including the carried propping agent) exists in the formation and considering the time-dependent decrease effect of the near-well formation pressure caused by the diffusion of the near-well formation fluid to the far-end formation along with the time change (figure 1). The stratum pressure calculated by the method can be used for obtaining the stratum dynamic productivity, avoids the oil testing risk and has great practical significance.
Finally, it should be noted that: the above examples are only specific embodiments of the present invention for illustrating the technical solution of the present invention, but not for limiting the scope of the present invention, and although the present invention has been described in detail with reference to the foregoing examples, it will be understood by those skilled in the art that the present invention is not limited thereto: any person skilled in the art may modify or easily conceive of the technical solution described in the foregoing embodiments, or perform equivalent substitution of some of the technical features, while remaining within the technical scope of the present disclosure; such modifications, changes or substitutions do not depart from the spirit and scope of the technical solutions of the embodiments of the present invention, and are intended to be included in the scope of the present invention. Therefore, the protection scope of the invention is subject to the protection scope of the claims.
Claims (8)
1. The method for solving the formation pressure after fracturing by considering the pressurization of the fluid retention amount is characterized by comprising the following steps of:
inputting geological parameters, engineering parameters and fracturing construction parameters of a target reservoir into a fracturing crack expansion model, simulating to obtain stratum pressure change of the target reservoir in the fracturing construction process, selecting stratum pressure when the ground entering liquid amount is the same as the ground stagnation liquid amount of the target reservoir, and taking the stratum pressure as initial stratum pressure under the influence of the ground stagnation liquid amount pressurization;
inputting the initial formation pressure into a pressure diffusion model to obtain a decreasing change rule of the formation pressure along with time after fracturing, and further obtaining the formation pressure at any moment according to the decreasing change rule of the formation pressure along with time.
2. The method for determining the post-fracture formation pressure taking into account the pressurization of the fluid-retention volume according to claim 1, wherein the fracture propagation model is a multi-fracture-mode PKN model.
3. The method for determining the post-fracture formation pressure taking into account the pressurization of the fluid-retention volume according to claim 1, wherein the expression of the pressure diffusion model is:
P(t)＝P e +(P b0 -P e )e -at
wherein:p (t) is the dynamic formation pressure after fracturing; p (P) e Is the original formation pressure; p (P) b0 The method comprises the steps of (1) setting an initial pressure of a near-well stratum under the influence of the pressurization of a ground stagnation liquid; a is the pressure diffusion rate index; t is time.
4. A post-fracture formation pressure determination method taking into account fluid-stagnation pressurization according to claim 1, wherein said geological parameters comprise: depth in the middle of the reservoir, reservoir thickness, clay content, porosity, permeability, and oil (gas) saturation.
5. The method of claim 1, wherein the engineering parameters include: formation pressure, young's modulus, poisson's ratio, biot coefficient, vertical principal stress, maximum horizontal principal stress, and minimum horizontal principal stress.
6. The method for determining the formation pressure after fracturing taking into account the pressurization of the fluid retention volume according to claim 1, wherein the fracturing construction parameters comprise: average displacement, fracturing time, fracturing fluid viscosity, fluid loss factor, total proppant and fluid retention.
7. The method for determining the post-fracture formation pressure taking into account the pressure increase of the fluid retention volume according to claim 1, wherein the diffusion coefficient in the pressure diffusion model is determined by the fracture wave and volume and the reservoir matrix permeability.
8. The method for obtaining the post-fracturing formation pressure taking the earth stagnation amount into account according to claim 7, wherein the diffusion coefficient in the pressure diffusion model is subjected to scale correction by using pressure test data of actual fracturing construction.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202010872835.1A CN111963149B (en) | 2020-08-26 | 2020-08-26 | Post-fracturing stratum pressure solving method taking earth stagnation amount pressurization into consideration |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202010872835.1A CN111963149B (en) | 2020-08-26 | 2020-08-26 | Post-fracturing stratum pressure solving method taking earth stagnation amount pressurization into consideration |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN111963149A CN111963149A (en) | 2020-11-20 |
| CN111963149B true CN111963149B (en) | 2024-03-01 |
Family
ID=73390751
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202010872835.1A Active CN111963149B (en) | 2020-08-26 | 2020-08-26 | Post-fracturing stratum pressure solving method taking earth stagnation amount pressurization into consideration |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN111963149B (en) |
Families Citing this family (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN112883444A (en) * | 2021-01-25 | 2021-06-01 | 中国石油天然气集团有限公司 | Fracture propagation model solving method and system considering fracture network complexity |
| CN113236238B (en) * | 2021-05-19 | 2022-03-01 | 西南石油大学 | Method for predicting compressibility index of laminated shale formation |
Citations (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2011081544A1 (en) * | 2009-12-30 | 2011-07-07 | Шлюмберже Холдингс Лимитед | Method for controlling the trajectory of a hydraulic fracture in strata containing natural fractures |
| CN104975852A (en) * | 2015-06-25 | 2015-10-14 | 中国石油大学(北京) | Diagnosis method of oil/gas output positions of multi-segment fracturing horizontal well and diagnosis system thereof |
| CN106640021A (en) * | 2016-12-01 | 2017-05-10 | 中国石油天然气股份有限公司 | Calculating method and device for post-fracture blow-off parameters |
| CN108180006A (en) * | 2017-12-25 | 2018-06-19 | 中国石油天然气股份有限公司 | A kind of HORIZONTAL WELL PRODUCTION FORECASTING METHODS being lifted based on stratum energy after volume fracturing |
| CN110939438A (en) * | 2019-10-14 | 2020-03-31 | 中国石油化工股份有限公司 | Method for evaluating after-pressure by using pressure drop of main fracturing pump stopping |
| US10689972B1 (en) * | 2019-05-31 | 2020-06-23 | Southwest Petroleum University | Automatic diagnosis method for wellhead pressure curve of hydraulic fracturing in shale gas horizontal well |
Family Cites Families (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US7031841B2 (en) * | 2004-01-30 | 2006-04-18 | Schlumberger Technology Corporation | Method for determining pressure of earth formations |
-
2020
- 2020-08-26 CN CN202010872835.1A patent/CN111963149B/en active Active
Patent Citations (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2011081544A1 (en) * | 2009-12-30 | 2011-07-07 | Шлюмберже Холдингс Лимитед | Method for controlling the trajectory of a hydraulic fracture in strata containing natural fractures |
| CN104975852A (en) * | 2015-06-25 | 2015-10-14 | 中国石油大学(北京) | Diagnosis method of oil/gas output positions of multi-segment fracturing horizontal well and diagnosis system thereof |
| CN106640021A (en) * | 2016-12-01 | 2017-05-10 | 中国石油天然气股份有限公司 | Calculating method and device for post-fracture blow-off parameters |
| CN108180006A (en) * | 2017-12-25 | 2018-06-19 | 中国石油天然气股份有限公司 | A kind of HORIZONTAL WELL PRODUCTION FORECASTING METHODS being lifted based on stratum energy after volume fracturing |
| US10689972B1 (en) * | 2019-05-31 | 2020-06-23 | Southwest Petroleum University | Automatic diagnosis method for wellhead pressure curve of hydraulic fracturing in shale gas horizontal well |
| CN110939438A (en) * | 2019-10-14 | 2020-03-31 | 中国石油化工股份有限公司 | Method for evaluating after-pressure by using pressure drop of main fracturing pump stopping |
Non-Patent Citations (1)
| Title |
|---|
| 页岩储层多段压裂后裂缝自然闭合压力递减规律;李勇明;王琰琛;马汉伟;;油气地质与采收率;23(第02期);102-106 * |
Also Published As
| Publication number | Publication date |
|---|---|
| CN111963149A (en) | 2020-11-20 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| Ostensen | The effect of stress-dependent permeability on gas production and well testing | |
| Barree et al. | Determination of pressure dependent leakoff and its effect on fracture geometry | |
| CN104018829B (en) | A kind of method that utilization coal bed gas well creation data measures air water phase percolation curve | |
| RU2362875C2 (en) | Method of evaluating pressure in underground reservoirs | |
| Roussel | Analyzing ISIP stage-by-stage escalation to determine fracture height and horizontal-stress anisotropy | |
| CN111963149B (en) | Post-fracturing stratum pressure solving method taking earth stagnation amount pressurization into consideration | |
| CN104899411B (en) | A kind of reservoir productivity prediction model method for building up and system | |
| Wang et al. | A novel approach for estimating formation permeability and revisiting after-closure analysis of diagnostic fracture-injection tests | |
| Lin et al. | A criterion for evaluating the efficiency of water injection in oil sand reservoirs | |
| US10385659B2 (en) | Evaluation of production performance from a hydraulically fractured well | |
| CN110043254B (en) | Method for obtaining stratum effective permeability based on cable stratum test data | |
| CN112412434B (en) | Improved loose sandstone ground stress calculation method | |
| CN105844011A (en) | Capillary model-based permeability computing method | |
| Yuan et al. | Improved rate-transient analysis for heterogeneous fractured liquid-rich tight reservoirs with non-static properties | |
| US11733423B2 (en) | Determination of a surface leak rate in an injection well | |
| CN114575831A (en) | Volume fracturing horizontal well productivity prediction method and device under advanced energy supplement development mode | |
| Pandey et al. | Vertical growth of hydraulic fractures in layered formations | |
| CN110630243B (en) | Method for determining fracturing fracture parameters based on fracturing well production data | |
| US20230030531A1 (en) | Real-Time Fracture Monitoring, Evaluation And Control | |
| Benelkadi et al. | Reservoir permeability determination using after-closure period analysis of calibration tests | |
| CN109975189B (en) | Method and device for predicting productivity of pore type sandstone reservoir | |
| Ayoub et al. | Diagnosis and evaluation of fracturing treatments | |
| CN109403942B (en) | Method for determining mixing ratio of slickwater and glue solution in shale gas well fracturing design | |
| AU2012382975B2 (en) | Method and apparatus for formation tester data interpretation with diverse flow models | |
| CN104712299B (en) | It is adapted to gas well control water and increases the design method that air pressure splits |
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 |