GB2612391A - Method for defining boundary of fracture flow state in natural gas reservoir - Google Patents
Method for defining boundary of fracture flow state in natural gas reservoir Download PDFInfo
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- GB2612391A GB2612391A GB2207330.8A GB202207330A GB2612391A GB 2612391 A GB2612391 A GB 2612391A GB 202207330 A GB202207330 A GB 202207330A GB 2612391 A GB2612391 A GB 2612391A
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- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 title claims abstract description 48
- 239000003345 natural gas Substances 0.000 title claims abstract description 24
- 238000000034 method Methods 0.000 title claims abstract description 20
- 239000007789 gas Substances 0.000 claims abstract description 56
- 238000001595 flow curve Methods 0.000 claims abstract description 22
- 238000002474 experimental method Methods 0.000 claims abstract description 9
- RYGMFSIKBFXOCR-UHFFFAOYSA-N Copper Chemical compound [Cu] RYGMFSIKBFXOCR-UHFFFAOYSA-N 0.000 claims description 18
- 229910052802 copper Inorganic materials 0.000 claims description 18
- 239000010949 copper Substances 0.000 claims description 18
- 238000009760 electrical discharge machining Methods 0.000 claims description 7
- 230000000087 stabilizing effect Effects 0.000 claims description 4
- 239000000463 material Substances 0.000 claims description 3
- BFKJFAAPBSQJPD-UHFFFAOYSA-N tetrafluoroethene Chemical group FC(F)=C(F)F BFKJFAAPBSQJPD-UHFFFAOYSA-N 0.000 claims description 3
- 239000007769 metal material Substances 0.000 claims description 2
- 206010017076 Fracture Diseases 0.000 description 115
- 208000010392 Bone Fractures Diseases 0.000 description 94
- 238000010586 diagram Methods 0.000 description 14
- 238000012360 testing method Methods 0.000 description 7
- 239000011435 rock Substances 0.000 description 5
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 4
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 4
- 239000004576 sand Substances 0.000 description 4
- 238000012986 modification Methods 0.000 description 3
- 230000004048 modification Effects 0.000 description 3
- 208000013201 Stress fracture Diseases 0.000 description 2
- 238000004364 calculation method Methods 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 230000001788 irregular Effects 0.000 description 2
- 238000005259 measurement Methods 0.000 description 2
- 239000002184 metal Substances 0.000 description 2
- 229910052751 metal Inorganic materials 0.000 description 2
- 229910052757 nitrogen Inorganic materials 0.000 description 2
- 238000004088 simulation Methods 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 1
- 229910001873 dinitrogen Inorganic materials 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- QJGQUHMNIGDVPM-UHFFFAOYSA-N nitrogen group Chemical group [N] QJGQUHMNIGDVPM-UHFFFAOYSA-N 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 238000009877 rendering Methods 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 238000010187 selection method Methods 0.000 description 1
Classifications
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
- G01N33/24—Earth materials
- G01N33/241—Earth materials for hydrocarbon content
-
- 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
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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- 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
- E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
- E21B2200/20—Computer models or simulations, e.g. for reservoirs under production, drill bits
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
- Y02A10/00—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE at coastal zones; at river basins
- Y02A10/40—Controlling or monitoring, e.g. of flood or hurricane; Forecasting, e.g. risk assessment or mapping
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Environmental & Geological Engineering (AREA)
- Physics & Mathematics (AREA)
- Health & Medical Sciences (AREA)
- Chemical & Material Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Fluid Mechanics (AREA)
- Analytical Chemistry (AREA)
- Food Science & Technology (AREA)
- Medicinal Chemistry (AREA)
- Remote Sensing (AREA)
- Biochemistry (AREA)
- General Health & Medical Sciences (AREA)
- General Physics & Mathematics (AREA)
- Immunology (AREA)
- Pathology (AREA)
- Investigating Strength Of Materials By Application Of Mechanical Stress (AREA)
- Testing Of Devices, Machine Parts, Or Other Structures Thereof (AREA)
Abstract
A method for defining the boundary of fracture flow state in a natural gas reservoir. The method involves conducting an experiment of simulating gas flow in a fracture by using an experimental facility for simulating seepage flow boundaries of fractures with different fracture widths, to obtain an actual curve of gas flow in fractures with different fracture widths. The theoretical pipe flow curve of gas flow in fractures with different fracture widths is calculated. The included angle between the actual curve and the theoretical pipe flow curve at each fracture width is calculated. The fracture height at the fracture width corresponding to each included angle is obtained. A relation curve of the included angle and the fracture height is plotted with the included angle as the x-axis and the fracture height as the y-axis. An inflection point of the relation curve is obtained as the boundary of fracture flow state in the natural gas reservoir. Preferably, the experimental facility comprises a gas source storage tank, a gas inlet pipe, a physical fracture model and an exhaust pipe that are connected to one another.
Description
METHOD FOR DEFINING BOUNDARY OF FRACTURE FLOW STATE IN NATURAL
GAS RESERVOIR
TECHNICAL FIELD
100011 The present disclosure relates to the technical field of the development of fractured gas reservoirs, and in particular to a method for defining the boundary of fracture flow state in a natural gas reservoir.
BACKGROUND ART
[0002] China possesses vast natural gas resources and abundant geological resources. Fractures may exist in both carbonate rock and clastic rock (e.g., tight sandstone) reservoirs. Fractures or pores may be more obvious especially in carbonate rocks. Fractures are not only reservoir space of oil and gas in carbonate rocks but also main channels for seepage flow of oil and gas. This is the main reason why half of oil and gas reserves and production in the world comes from carbonate rocks. If the flow forms and flow ability of gases in fractures under different closure conditions can be defined, gas deliverability can be calculated accurately by using an equation. Then, a flow law in different fractures in strata can be known exactly. For tests of simulated fracture flow, there are still no uniform measurement standard and method in and outside China. Some scholars conducted research on experimental methods. However, most of such methods were conclusions from a macroscopic perspective, and no method that accurately defines a microscopic flow boundary of a fracture was proposed.
S U NI MARY
100031 To address the above-mentioned problems, the present disclosure provides a method for defining the boundary of fracture flow state in a natural gas reservoir.
[0004] The technical solutions of the present disclosure are described below.
[0005] A method for defining the boundary of fracture flow state in a natural gas reservoir includes the following steps: [0006] conducting an experiment of simulating gas flow in a fracture by using an experimental facility for simulating seepage flow boundaries of fractures with different fracture widths, to obtain an actual curve of gas flow in fractures with different fracture widths; 100071 calculating a theoretical pipe flow curve of gas flow in fractures with different fracture widths; [0008] calculating an included angle between the actual curve and the theoretical pipe flow curve at each fracture width; [0009] obtaining a fracture height at the fracture width corresponding to each included angle, and plotting a relation curve of the included angle and the fracture height with the included angle as the x-axis and the fracture height as the y-axis; and [0010] obtaining an inflection point of the relation curve as the boundary of fracture flow state in the natural gas reservoir.
[0011] Preferably, the experimental facility for simulating seepage flow boundaries of fractures may include a gas source storage tank, a gas inlet pipe, a physical fracture model and an exhaust pipe that are orderly connected to one another. A first pressure sensor, a pressure reducing valve and a second pressure sensor may be orderly disposed on the gas inlet pipe. A third pressure sensor and a gas flowmeter may be orderly disposed on the exhaust pipe.
[0012] Preferably, the physical fracture model may be designed with a spark-erosion perforated ultrafine copper tube having an inner diameter of less than 1 mm to simulate a fracture channel. The ultrafine copper tube may be flattened to obtain a fracture having a different fracture width. [0013] Preferably, two ends of the physical fracture model may be connected to the gas inlet pipe and the exhaust pipe by means of a ring pressure hoop and an adapter, respectively.
[0014] Preferably, the ring pressure hoop may be made of a tetrafluoroethylene material, and the adapter may be made of a metal material.
[0045] Preferably, a pressure difference between the two ends of the physical fracture model may be controlled within 1 M1Pa to ensure that flow is simulated to linear flow.
[0016] Preferably, a pressure stabilizing valve may be further disposed on the gas inlet pipe between the pressure reducing valve and the second pressure sensor.
[0017] Preferably, the theoretical pipe flow curve may be plotted based on Hagen-Poiseuille theoretical calculated values.
[0018] The present disclosure has the following beneficial effects: [0019] The present disclosure allows for definition of the boundary of fracture flow state in a natural gas reservoir based on an inflection point of a relation curve of an included angle between an actual curve of gas flow in a fracture and a theoretical pipe flow curve and a fracture height, and thus provides technical support for the development of fractured gas reservoirs.
BRIEF DESCRIPTION OF THE DRAWINGS
[0020] To describe the technical solutions in embodiments of the present disclosure or in the prior art more clearly, the accompanying drawings required in the embodiments will be briefly described below. Apparently, the accompanying drawings in the following description show merely some embodiments of the present disclosure, and other drawings can be derived from the accompanying drawings by those of ordinary skill in the art without creative efforts [0021] FIG 1 is a structural schematic diagram of an experimental facility for simulating seepage flow boundaries of fractures according to an embodiment of the present disclosure. [0022] FIG. 2 is a schematic diagram illustrating a scanning electron microscope (SEM) (300 pm) test result of the interior of a physical fracture model according to the present disclosure. [0023] FIG. 3 is a schematic diagram illustrating an SEM (20 pm) test result of the interior of the physical fracture model according to the present disclosure.
100241 FIG. 4 is a schematic diagram illustrating an actual curve of gas flow in fractures with different fracture widths according to an embodiment of the present disclosure.
[0025] FIG. 5 is a schematic diagram illustrating a theoretical pipe flow curve of gas flow in fractures with different fracture widths according to an embodiment of the present disclosure. [0026] FIG. 6 is a schematic diagram illustrating a comparison of the actual curve with the theoretical pipe flow curve with a fracture width of 0.41 mm and a fracture height of 0.4 mm. [0027] FIG. 7 is a schematic diagram illustrating a comparison of the actual curve with the theoretical pipe flow curve with a fracture width of 0.43 mm and a fracture height of 0.36 mm. [0028] FIG. 8 is a schematic diagram illustrating a comparison of the actual curve with the theoretical pipe flow curve with a fracture width of 0.4 mm and a fracture height of 0.33 mm. [0029] FIG. 9 is a schematic diagram illustrating a comparison of the actual curve with the theoretical pipe flow curve with a fracture width of 0.4 mm and a fracture height of 0.25 mm. [0030] FIG. 10 is a schematic diagram illustrating a comparison of the actual curve with the theoretical pipe flow curve with a fracture width of 0.38 mm and a fracture height of 0.2 mm. [0031] FIG. 11 is a schematic diagram illustrating a comparison of the actual curve with the theoretical pipe flow curve with a fracture width of 0.45 mm and a fracture height of 0.16 mm. [0032] FIG. 12 is a schematic diagram illustrating a comparison of the actual curve with the theoretical pipe flow curve with a fracture width of 0.51 mm and a fracture height of 0.11 mm. [0033] FIG. 13 is a schematic diagram illustrating a comparison of the actual curve with the theoretical pipe flow curve with a fracture width of 0.53 mm and a fracture height of 0.08 mm. [0034] FIG. 14 is a schematic diagram illustrating a result of a relation curve of an included angle and a fracture height according to an embodiment of the present disclosure.
DETAILED DESCRIPTION OF THE EMBODIMENTS
[0035] The present disclosure is described in further detail below with reference to the drawings and embodiments. It should be noted that the embodiments in the present disclosure and the technical features in the embodiments can be combined with one another without conflict. It should be noted that unless otherwise specified, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the technical field to which the present disclosure belongs The words "including', "comprising" and the like used herein mean that an element or article appearing before the word includes elements or articles and their equivalent elements appearing behind the word, not excluding any other elements or articles.
100361 The present disclosure provides a method for defining the boundary of fracture flow state in a natural gas reservoir, including the following steps: 100371 Sl: conduct an experiment of simulating gas flow in a fracture by using an experimental facility for simulating seepage flow boundaries of fractures with different fracture widths, to obtain an actual curve of gas flow in fractures with different fracture widths.
[0038] In a specific embodiment, as shown in FIG. 1, the experimental facility for simulating seepage flow boundaries of fractures include a gas source storage tank, a gas inlet pipe, a physical fracture model and an exhaust pipe that are orderly connected to one another. A first pressure sensor, a pressure reducing valve and a second pressure sensor are orderly disposed on the gas inlet pipe. A third pressure sensor and a gas flowmeter are orderly disposed on the exhaust pipe. The physical fracture model is designed with a spark-erosion perforated ultrafine copper tube having an inner diameter of less than 1 mm to simulate a fracture channel. The ultrafine copper tube is flattened to obtain a fracture with a unique fracture width. Two ends of the physical fracture model are connected to the gas inlet pipe and the exhaust pipe by means of a ring pressure hoop and an adapter, respectively.
100391 In the above embodiment, the fracture surface is formed by the flattened spark-erosion perforated ultrafine copper tube, as shown in FIG. 2 and FIG. 3, which has irregular micro-bulge structures having different heights to simulate an actual uneven fracture surface. Moreover, the flattened spark-erosion perforated ultrafine copper tube has the micro-fracture characteristic and is capable of simulating fracture widths from a large one to a small one. The fracture surface with irregular micro-bulges is gradually coupled and transformed from free flow space to seepage flow space such that the simulation results can be more realistic.
[0040] In a specific embodiment, to ensure that flow is simulated to linear flow, a pressure difference between the two ends of the physical fracture model is optionally controlled within 1 MPa. To ensure that flow is simulated to linear flow and guarantee the accuracy, optionally, a pressure stabilizing valve is further disposed on the gas inlet pipe between the pressure reducing valve and the second pressure sensor.
[0041] In the above embodiment, a gas flow simulation test is performed under a low pressure difference, which may accord with the actual situation in actual gas reservoir exploitation, rendering the results more realistic.
[0042] In a specific embodiment, when an experiment of simulating gas flow in a fracture is conducted by using the experimental facility for simulating seepage flow boundaries of fractures described in the above embodiment, specific steps are as follows: [0043] (1) use the spark-erosion perforated ultrafine copper tube having the inner diameter of less than 1 mm to simulate the fracture channel, split the copper tube, obtain an internal microstructure image of the copper tube by scanning using a field emission scanning electron microscope to check whether the real uneven fracture is perfectly simulated; 100441 (2) after determining that the real uneven fracture is perfectly simulated, flatten the copper tube to simulate a micro-fracture in a stratum, and plastically press the ultrafine copper tube under a different external force to obtain physical fracture models with different fracture width; [0045] (3) connect the flattened copper tube fracture with the metal adapter by using the ring pressure hoop made of the tetrafluoroethylene material, and attach the metal adapter to an experimental gas source cylinder; and [0046] (4) inject nitrogen into the copper tube fracture at different inlet pressures, and meter flow rates at the outlet end and inlet and outlet pressures.
100471 It needs to be noted that in addition to the nitrogen gas source used in the above embodiment, a simulated natural gas may also be used in the experiment in the present disclosure. When the simulated natural gas is used in the experiment, the exhaust pipe is further connected to an exhaust storage tank.
100481 S2: calculate a theoretical pipe flow curve of gas flow in fractures with different fracture widths. The theoretical pipe flow curve is plotted based on Hagen-Poiseuille theoretical calculated values.
[0049] It needs to be noted that the use of Hagen-Poiseuille theoretical calculated values (i.e., the flow ability of a gas in a smooth fracture in an ideal condition) is the prior art and the specific calculation method will not be redundantly described herein.
[0050] S3: calculate an included angle between the actual curve and the theoretical pipe flow curve at each fracture width.
100511 S4: obtain a fracture height at the fracture width corresponding to each included angle, and plot a relation curve of the included angle and the fracture height with the included angle as the x-axis and the fracture height as the y-axis. The inflection point of the relation curve is the boundary of fracture flow state in the natural gas reservoir.
100521 In a specific embodiment, the method for defining the boundary of fracture flow state in a natural gas reservoir provided in the present disclosure is applied to define the boundary of fracture flow state, which specifically includes the following steps: [0053] (1) plastically flatten a spark-erosion perforated ultrafine copper tube having an inner diameter of 0.32 mm and a length of 40 cm to obtain simulated fracture models having different fracture widths of 0.38 mm, 0.4 mm, 0.41 mm, 0.43 mm, 0.45 mm, 0.48 mm, and 0.58 mm to simulate fracture channels, and connect one end of each simulated fracture model to a gas source and the other end to a gas flowmeter; 100541 (2) set the inlet pressure to 550 kPa, 500 kPa, 450kPa, 400 kPa, 350 kPa, 300 kPa, 250 kPa, 200 kPa, 150 kPa, 120 kPa, 100 kPa, 80 kPa, 60 kPa and 40 kPa, separately to perform gradient measurement on gas flow in the fractures, to obtain the actual curve of gas flow in the fractures with different fracture widths, with the results shown in FIG. 4; [0055] (3) calculate the gas flow abilities in a smooth fracture in an ideal condition for the fractures having different sizes formed by plastically flattening the copper tube by using the Hagen-Poiseuille flow equation, with the results shown in FIG. 5; 100561 (4) compare a stable linear flow segment selected from the experimental values with the Hagen-Poiseuille theoretical values, with the results shown in FIG. 6 to FIG. 13; [0057] (5) according to the results shown in FIG. 6 to FIG. 13, calculate an included angle between the actual curve and the theoretical pipe flow curve, and obtain the fracture height at the fracture width corresponding to the included angle; and 100581 (6) plot the relation curve of the included angle and the fracture height with the included angle as the x-axis and the fracture height as the y-axis, with the result shown in FIG. 14. The inflection point (fracture width=0.2 mm) of the relation curve is the boundary of fracture flow state in the natural gas reservoir.
[0059] It needs to be noted that in this embodiment, the gas source in the gas source storage tank is nitrogen, and the outlet end of the exhaust pipe is directly communicated with the atmosphere. The test is performed under a low pressure. To ensure the accuracy of the experiment, a pressure stabilizing valve is disposed on the air inlet pipe in the testing facility used in this embodiment. The selection of the stable linear flow segment in step (4) is the prior art, and the specific selection method will not be redundantly described herein.
[0060] In another specific embodiment, the ultrafine copper tube may be filled with sand with different sizes (e.g., 300-600 mesh, 600-900 mesh, 900-1,200 mesh) for testing. Thus, a relation between the flow state in the fracture filled with sand having a different size and the sand can be obtained, and the degree of the influence of the sand having a different size filling the fracture on the flow ability can be exactly known, thus providing basis for the calculation of the flow ability of a gas in fractures.
[0061] The foregoing are merely descriptions of the preferred embodiments of the present disclosure and not intended to limit the present disclosure in any form. Although the present disclosure has been disclosed above by the preferred embodiments, these embodiments are not intended to limit the present disclosure. Any person skilled in the art may make some changes or modifications to implement equivalent embodiments with equivalent changes by using the technical contents disclosed above without departing from the scope of the technical solutions of the present disclosure. Any simple modification, equivalent change and modification made to the foregoing embodiments according to the technical essence of the present disclosure without departing from the contents of the technical solutions of the present disclosure shall fall within the scope of the technical solutions of the present disclosure.
Claims (8)
- WHAT IS CLAIMED IS: I. A method for defining the boundary of fracture flow state in a natural gas reservoir, comprising the following steps: conducting an experiment of simulating gas flow in a fracture by using an experimental facility for simulating seepage flow boundaries of fractures with different fracture widths, to obtain an actual curve of gas flow in fractures with different fracture widths; calculating a theoretical pipe flow curve of gas flow in fractures with different fracture widths; calculating an included angle between the actual curve and the theoretical pipe flow curve at each fracture width; obtaining a fracture height at the fracture width corresponding to each included angle, and plotting a relation curve of the included angle and the fracture height with the included angle as the x-axis and the fracture height as the y-axis; and obtaining an inflection point of the relation curve as the boundary of fracture flow state in the natural gas reservoir.
- 2. The method for defining the boundary of fracture flow state in a natural gas reservoir according to claim 1, wherein the experimental facility for simulating seepage flow boundaries of fractures comprises a gas source storage tank, a gas inlet pipe, a physical fracture model and an exhaust pipe that are orderly connected to one another; a first pressure sensor, a pressure reducing valve and a second pressure sensor are orderly disposed on the gas inlet pipe; and a third pressure sensor and a gas flowmeter are orderly disposed on the exhaust pipe.
- 3. The method for defining the boundary of fracture flow state in a natural gas reservoir according to claim 2, wherein the physical fracture model is designed with a spark-erosion perforated ultrafine copper tube having an inner diameter of less than 1 mm to simulate a fracture channel; and the ultrafine copper tube is flattened to obtain a fracture having a different fracture width.
- 4 The method for defining the boundary of fracture flow state in a natural gas reservoir according to claim 3, wherein two ends of the physical fracture model are connected to the gas inlet pipe and the exhaust pipe by means of a ring pressure hoop and an adapter, respectively.
- The method for defining the boundary of fracture flow state in a natural gas reservoir according to claim 4, wherein the ring pressure hoop is made of a tetrafluoroethylene material, while the adapter is made of a metal material.
- 6. The method for defining the boundary of fracture flow state in a natural gas reservoir according to claim 2, wherein a pressure difference between the two ends of the physical fracture model is controlled within 1 MPa to ensure that flow is simulated to linear flow.
- 7. The method for defining the boundary of fracture flow state in a natural gas reservoir according to claim 6, wherein a pressure stabilizing valve is further disposed on the gas inlet pipe between the pressure reducing valve and the second pressure sensor.
- 8 The method for defining the boundary of fracture flow state in a natural gas reservoir according to any one of claims 1 to 7, wherein the theoretical pipe flow curve is plotted based on Hagen-Poi seuille theoretical calculated values.
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| CN202111272165.0A CN113803063B (en) | 2021-10-29 | 2021-10-29 | Method for defining flow state limit of reservoir cracks of natural gas reservoir |
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| GB202207330D0 GB202207330D0 (en) | 2022-07-06 |
| GB2612391A true GB2612391A (en) | 2023-05-03 |
| GB2612391B GB2612391B (en) | 2023-12-20 |
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Citations (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US20100250216A1 (en) * | 2009-03-24 | 2010-09-30 | Chevron U.S.A. Inc. | System and method for characterizing fractures in a subsurface reservoir |
| CN108343433A (en) * | 2018-02-28 | 2018-07-31 | 西南石油大学 | Method for calculating gaseous mass configured transmission under shale microcrack changes of slit length |
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4817062A (en) * | 1987-10-02 | 1989-03-28 | Western Atlas International, Inc. | Method for estimating subsurface porosity |
| WO1991004500A1 (en) * | 1989-09-20 | 1991-04-04 | Chevron Research And Technology Company | Pore pressure prediction method |
| CN101139925B (en) * | 2006-09-08 | 2012-07-04 | 西南石油大学 | Method for while-drilling testing reservoir parameter property and adjusting well drilling action in real time |
| US20170051598A1 (en) * | 2015-08-20 | 2017-02-23 | FracGeo, LLC | System For Hydraulic Fracturing Design And Optimization In Naturally Fractured Reservoirs |
| US10467362B2 (en) * | 2018-01-19 | 2019-11-05 | Nikolai Kislov | Analytical tools and methods for modeling transport processes in fluids |
| CN111236908A (en) * | 2020-01-09 | 2020-06-05 | 西南石油大学 | Multi-stage fractured horizontal well productivity prediction model and productivity sensitivity analysis method suitable for low-permeability tight gas reservoir |
| CN111963158B (en) * | 2020-08-12 | 2022-04-01 | 西南石油大学 | Method for calculating permeability of matrix after acid fracturing of carbonate rock |
| CN111927420A (en) * | 2020-08-15 | 2020-11-13 | 西南石油大学 | Method for simulating pressure of asymmetric fractured well with limited diversion for gas reservoir in any shape |
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Patent Citations (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US20100250216A1 (en) * | 2009-03-24 | 2010-09-30 | Chevron U.S.A. Inc. | System and method for characterizing fractures in a subsurface reservoir |
| CN108343433A (en) * | 2018-02-28 | 2018-07-31 | 西南石油大学 | Method for calculating gaseous mass configured transmission under shale microcrack changes of slit length |
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| CN113803063B (en) | 2023-08-22 |
| GB2612391B (en) | 2023-12-20 |
| CN113803063A (en) | 2021-12-17 |
| GB202207330D0 (en) | 2022-07-06 |
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