CN114776264A - Solid phase control method in natural gas hydrate exploitation process - Google Patents
Solid phase control method in natural gas hydrate exploitation process Download PDFInfo
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- 239000007790 solid phase Substances 0.000 title claims abstract description 96
- 238000000034 method Methods 0.000 title claims abstract description 47
- NMJORVOYSJLJGU-UHFFFAOYSA-N methane clathrate Chemical compound C.C.C.C.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O NMJORVOYSJLJGU-UHFFFAOYSA-N 0.000 title claims abstract description 21
- 230000008569 process Effects 0.000 title claims abstract description 14
- 239000002245 particle Substances 0.000 claims abstract description 69
- 239000004576 sand Substances 0.000 claims abstract description 58
- 238000004519 manufacturing process Methods 0.000 claims abstract description 30
- 238000002474 experimental method Methods 0.000 claims abstract description 16
- 238000011217 control strategy Methods 0.000 claims abstract description 15
- 150000004677 hydrates Chemical class 0.000 claims abstract description 15
- 238000005065 mining Methods 0.000 claims abstract description 7
- 238000012216 screening Methods 0.000 claims abstract description 6
- 239000007789 gas Substances 0.000 claims description 25
- 239000012530 fluid Substances 0.000 claims description 16
- 230000015572 biosynthetic process Effects 0.000 claims description 6
- 239000007788 liquid Substances 0.000 claims description 6
- 239000007787 solid Substances 0.000 claims description 6
- 230000008878 coupling Effects 0.000 claims description 5
- 238000010168 coupling process Methods 0.000 claims description 5
- 238000005859 coupling reaction Methods 0.000 claims description 5
- 230000008859 change Effects 0.000 claims description 3
- 238000001914 filtration Methods 0.000 claims description 3
- 239000012071 phase Substances 0.000 claims description 3
- 238000009288 screen filtration Methods 0.000 claims description 3
- 238000012856 packing Methods 0.000 claims 1
- 230000009467 reduction Effects 0.000 abstract description 4
- 230000009286 beneficial effect Effects 0.000 abstract description 2
- 238000005243 fluidization Methods 0.000 description 5
- 230000002265 prevention Effects 0.000 description 5
- 238000013461 design Methods 0.000 description 4
- 238000011161 development Methods 0.000 description 4
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 4
- 239000003345 natural gas Substances 0.000 description 3
- 239000011148 porous material Substances 0.000 description 3
- 238000000354 decomposition reaction Methods 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- -1 natural gas hydrates Chemical class 0.000 description 2
- 239000013049 sediment Substances 0.000 description 2
- 239000002689 soil Substances 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 230000009471 action Effects 0.000 description 1
- 230000000903 blocking effect Effects 0.000 description 1
- 239000002131 composite material Substances 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 238000007599 discharging Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
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- 238000012986 modification Methods 0.000 description 1
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- 239000008239 natural water Substances 0.000 description 1
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- 230000005641 tunneling Effects 0.000 description 1
- 230000007306 turnover Effects 0.000 description 1
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/02—Subsoil filtering
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
- E21B41/0099—Equipment or details not covered by groups E21B15/00 - E21B40/00 specially adapted for drilling for or production of natural hydrate or clathrate gas reservoirs; Drilling through or monitoring of formations containing gas hydrates or clathrates
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
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- 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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Abstract
The invention discloses a solid phase control method in a natural gas hydrate exploitation process, which comprises the following steps: acquiring reservoir data, calculating median particle sizes of hydrates and sand of solid phases of different reservoirs, and determining the comprehensive particle size of the solid phase of each reservoir by taking the volume ratio of the hydrates and the volume ratio of the sand in the solid phase of each reservoir as the weight of the median particle size; determining the precision range of the solid phase control strategies corresponding to different mining methods according to the comprehensive granularity; determining the control flow rate range of the shaft according to the secondary hydrate generation temperature and pressure range and the sand-carrying critical speed range in the shaft; and screening out the optimal solid phase control precision range and the optimal control flow rate range from the control precision range and the control flow rate range according to the requirement between the sand production amount and the productivity through experiments. The beneficial effects of the invention are: the problems of sand blockage caused by reduction of the flow speed in sand control, ice blockage caused by secondary generation of combustible ice, solid-phase co-blockage and the like are avoided.
Description
Technical Field
The invention relates to the technical field of natural gas hydrate exploitation, in particular to a solid phase control method in a natural gas hydrate exploitation process.
Background
The natural gas hydrate is an ice substance formed by natural gas and water under the conditions of low temperature and high pressure, is commonly called as 'combustible ice', is widely distributed in deep sea sediments or land frozen soil, and has abundant gas and fresh water reserves. However, most natural gas hydrate reservoirs are muddy silt reservoirs with deep water shallow layers, non-diagenesis and weak cementation, and engineering and geological risks such as sand production, well wall instability, seabed landslide and the like are easy to occur in the mining process.
However, the trial production of natural gas hydrates in frozen soil areas and sea areas is mostly limited by the sand production situation, particularly, in muddy silt reservoirs with multiple 'three shallow' disasters and development of unconsolidated, weakly consolidated or fractured cracks in China, the sand production phenomenon is the limit of conventional oil gas sand control, the sand production phenomenon is difficult to avoid in the hydrate production process, the sand control can cause secondary generation of well bore hydrates, and solid-phase blockage is easy to cause together with well bore sand carrying, so the influence of solid phases such as sand production/sand control/well bore sand carrying/secondary hydrate generation in the natural gas hydrate production process needs to be considered, and a corresponding solid-phase control method is adopted, so that the efficient and safe development of the hydrates can be ensured.
Disclosure of Invention
Aiming at the problems, the invention provides a solid phase control method in the natural gas hydrate exploitation process, which mainly solves the problems of solid phase blockage caused by secondary generation of a large amount of well bore hydrates and reduction of sand carrying in a well bore due to exploitation sand production and sand control.
In order to solve the technical problems, the technical scheme of the invention is as follows:
a solid phase control method in a natural gas hydrate exploitation process comprises the following steps:
acquiring reservoir data, calculating median particle sizes of hydrates and sand of solid phases of different reservoirs, and determining the comprehensive particle size of the solid phase of each reservoir by taking the volume ratio of the hydrates and the volume ratio of the sand in the solid phase of each reservoir as the weight of the median particle size;
determining the precision ranges of solid phase control strategies corresponding to different mining methods according to the comprehensive particle size;
determining the control flow rate range of the shaft according to the secondary generation temperature and pressure range of the hydrate in the shaft and the sand-carrying critical speed range;
and screening out an optimal solid phase control precision range and an optimal control flow rate range from the precision range and the control flow rate range through experiments according to the requirement between the sand production amount and the productivity.
In some embodiments, the reservoir data is obtained from survey data and hold pressure cores.
In some embodiments, the reservoir data includes a sand particle size, a hydrate saturation, and a formation porosity, and the hydrate volume fraction and the sand volume fraction are calculated from the hydrate saturation and the formation porosity.
In some embodiments, the method for calculating the comprehensive particle size is
In the formula (d)g50Is the weighted median particle size of the solid phase, dh50Is the median particle size of the hydrate, ds50Is the median particle size of the silt，ShAs the proportion of hydrates in the reservoir volume, SsIs the proportion of sand in the reservoir volume.
In some embodiments, the solid phase control strategy comprises a first stage control of gravel filtration with a median particle size precision in the range of 5-6 times the combined particle size and a second stage control of screen filtration with a pore size precision in the range of 1-1.1 times the combined particle size.
In some embodiments, the hydrate secondary generation temperature, the pressure range and the sand-carrying critical speed range in the wellbore are input into a multi-field coupling model of a wellbore temperature field-flow field-force field-phase change field, constraint conditions are set, and the control flow rate range is obtained through solving.
In some embodiments, the tool within the accuracy range is mounted on an experimental device, a fluid solid phase control experiment is carried out according to the accuracy range and the control flow rate range, a function between the sand production amount and the productivity is obtained according to an experiment result, and the optimal solid phase control accuracy and the optimal control flow rate are screened according to the function.
In some embodiments, the fluid solids control experiment comprises: gas and liquid fluids at different pressures, temperatures and flow rates are passed through a tool that simulates a reservoir and has a particular accuracy.
The beneficial effects of the invention are as follows: the method mainly comprises the steps of setting solid phase control strategies of different levels by considering the comprehensive particle sizes of different reservoirs according to the comprehensive particle sizes, screening the optimal solid phase control precision and the optimal control flow rate according to the relation between the sand production amount and the productivity, and effectively avoiding the problems of sand blockage caused by reduction of the flow rate in sand control, ice blockage caused by secondary generation of combustible ice, solid phase co-blockage and the like.
Drawings
Fig. 1 is a schematic flow chart of a solid phase control method in a natural gas hydrate exploitation process according to an embodiment of the present invention;
FIG. 2 is a schematic diagram of a solid phase control scheme under different scenarios according to an embodiment of the present invention.
Detailed Description
In order to make the objects, technical solutions and advantages of the present invention clearer and clearer, the following detailed description of the present invention is made with reference to the accompanying drawings and detailed description. It is to be understood that the specific embodiments described herein are merely illustrative of the invention and are not limiting of the invention. It should be further noted that, for the convenience of description, only some but not all of the relevant elements of the present invention are shown in the drawings.
The embodiment provides a solid phase control method in a natural gas hydrate exploitation process, which mainly considers comprehensive particle sizes of different reservoirs, sets solid phase control strategies of different levels according to the comprehensive particle sizes, screens optimal solid phase control precision and optimal control flow rate according to the relation between sand yield and productivity, and can effectively avoid sand blockage caused by flow rate reduction in sand control, ice blockage caused by secondary generation of combustible ice, solid phase co-blockage and other problems.
As shown in fig. 1, the method comprises the following steps:
and S1, acquiring reservoir data, calculating the median of the particle sizes of the hydrates and the sands of different reservoir solid phases, and determining the comprehensive particle size of each reservoir solid phase by taking the volume proportion of the hydrates and the volume proportion of the sands in each reservoir solid phase as the weight of the median of the particle sizes.
In this example, the reservoir data is obtained from survey data and hold pressure cores. And the reservoir data comprises the silt particle size, the hydrate saturation and the formation porosity, and the hydrate volume ratio and the silt volume ratio are calculated according to the hydrate saturation and the formation porosity.
The method for calculating the comprehensive particle size comprises the following steps
In the formula (d)g50Is the weighted median particle size of the solid phase, dh50Is the median particle size of the hydrate, ds50Is the median particle size of the silt, ShAs the proportion of hydrates in the reservoir volume，SsIs the proportion of sand in the reservoir volume.
And S2, determining the precision range of the solid phase control strategy corresponding to different mining methods according to the comprehensive granularity.
In the process of hydrate exploitation, the median value of the particle size of solid phase particles of a reservoir is not greatly changed, and although the particle size of the hydrate is reduced, the particle size of residual sand is increased. Thus, in this example, the solid phase control strategy includes at least a first level of control and a second level of control, the first level of control being gravel filtration, the median size precision of the gravel being in the range of 5-6 times the combined size, the second level of control being screen filtration, the screen having a pore size precision of 1-1.1 times the combined size.
And S3, determining the control flow rate range of the shaft according to the secondary generation temperature and pressure range of the hydrate in the shaft and the sand-carrying critical speed range.
In this embodiment, the secondary generation temperature, pressure range and sand-carrying critical speed range of the hydrate in the wellbore are input into a multi-field coupling model of a wellbore temperature field-flow field-force field-phase change field, constraint conditions are set, and a control flow rate range is obtained by solving.
And S4, screening out the optimal solid phase control precision range and the optimal control flow rate range from the precision range and the control flow rate range according to the requirement between the sand production amount and the productivity through experiments.
In this embodiment, the tool within the accuracy range is mounted on an experimental device, a fluid solid-phase control experiment is performed according to the accuracy range and the control flow rate range, a function between the sand production amount and the productivity is obtained according to the experiment result, and the optimal solid-phase control accuracy and the optimal control flow rate are screened according to the function. The fluid solid phase control experiment comprises the following steps: gas and liquid fluids at different pressures, temperatures and flow rates are passed through a tool that simulates a reservoir and has a particular accuracy.
Aiming at multiple levels, multiple mining modes and multiple production stages of a natural gas hydrate reservoir, considering the median particle size of solid phase particles of the reservoir and the principle of layered, staged and graded multilevel sand prevention: the design of different solid phase control precision (grading) is carried out by adopting the solid phase particle size median characteristics of each layer (layering) at different production stages (grading), and the multi-stage solid phase control (grading) is realized for the reservoir with high argillaceous content by adopting a composite sand control mode combining gravel, screen sand control and the like.
Based on natural gas hydrate development grading, large-particle hydrates are provided with a sand blocking effect on argillaceous silt by considering different particle sizes, so that the sand prevention design precision is influenced, a solid-phase control strategy is provided by considering hydrate particles and decomposition effects of the hydrate particles, and finally a solid-phase control method integrating sand production/sand prevention/shaft sand carrying/secondary generation prevention is formed, so that reference is provided for safe and efficient commercial development of the south China sea natural gas hydrates.
On the basis of the solid phase control method in the natural gas hydrate exploitation process, the following three different cases are illustrated, as shown in fig. 2:
(1) control strategy for exploiting hydrate based on conventional oil-gas technology
The first stage of production: by referring to the Saucier method, according to the median dg of the particle size of solid-phase particles (including mud sand and hydrate) of the stratum50And (5) carrying out primary screening. Under the condition of stable well wall, determining the precision range of the first-stage control, producing partial small-particle solid phase (small-particle hydrate and mud) at the first stage as much as possible, and preventing partial large-particle solid phase (large-particle hydrate and sand); for the reservoir with high argillaceous content, on the basis of the control mode, a Geoform sand prevention mode and a Tausch mode are adopted&And determining the precision range by technologies such as a Corley method, a Karpoff method, reservoir transformation and the like.
The second stage of production: with decomposition of the hydrate, dg50The weight of hydrate is reduced, and the larger solid-phase particles prevented in the stratum are the main solid-phase control body (mainly silt) at the stage, so that the accuracy range of the second-stage control of the pipe control accuracy is determined by combining the silt particle size obtained by reservoir exploratory well; for reservoirs with high shale content, in spite of the first-level control measures, the first-level control measures still need to be considered and then remedied by using second-level measures after the first-level control measures fail. At the moment, because the water content of the reservoir is lower than that of the first stage of production, the weight of the solid hydrate is reduced, but the gas flow rate is higher, the pipe sand control mode of the high-yield gas well can be considered, and the control can be carried out under the coordination of mud cakes。
Third stage of production: due to dg50The weight of the medium hydrate is further reduced, and an unstable reservoir or a mud cake decomposed by the hydrate on the near-well wall needs to be prevented from being wholly pushed by far-end gas and liquid to slide and produce sand, so that a third-stage control measure after the control failure of the first two stages also needs to be considered under the action of the first two stages of control measures. In the stage, the integral slippage of the reservoir after the near-borehole wall hydrate is decomposed is controlled.
S1: the median particle size of sediment of the south China sea hydrate reservoir stratum is 6-40 mu m, the average stratum porosity is 30-46% (40%) and the average hydrate saturation is 40-46.2% (43%). Therefore, the hydrate accounts for 17.2%, the sand accounts for 60%, and the pore accounts for 22.8% of the reservoir. The average particle size of the hydrate was taken to be 200. mu.m. The median particle size of the solid phase of the reservoir is the weighted average particle size of the solid phase of the reservoir, and the median particle size dg of the solid phase of the reservoir is calculated5038-58.4 mu m, and controlling the median value Dg of the gravel particle size of the solid phase 505 to 6 times dg50I.e., 190-350.4 μm, about 42-80 mesh, and the comparison shows that the high-grade screen pipe can take 60 μm as the control range, but the slotted liner pipe may not be suitable. Therefore, the gravel with the median particle size of 190-350.4 mu m can be adopted in the first-stage control, and the high-grade and high-quality sieve tube with the second-stage control range can adopt 60 mu m as the control range.
And S2, determining the flow rate in the critical sand-carrying zone of the shaft and the flow rate outside the secondary hydrate generation range through the multi-field coupling model of the hydrate shaft.
And S3, selecting an industrial common precision control tool to be put into experimental equipment for carrying out a fluid solid-phase control experiment to obtain the relation between the solid-phase output and the productivity, and further obtaining the required optimal solid-phase control precision.
(2) Control strategy for solid state fluidization
S1, the solid fluidization method for extracting the hydrate is mechanically controlled through pipes, and needs to control crushed solid-phase particles in the fluidized liquid, so as to avoid blockage caused by suction of large-particle solid phase which is not crushed and adhesion and blockage of fine-particle solid phase. And acquiring the solid phase particle size after tunneling and crushing, performing multi-stage control design in the fluidized pipe, realizing the control of sand overturning and discharging separation, and determining the precision of a solid phase control strategy. .
And S2, determining the flow velocity in critical sand carrying of the fluidization pipeline and the flow velocity outside the hydrate secondary generation range through a hydrate shaft (fluidization pipeline) multi-field coupling model, and determining the fluid flow velocity range.
And S3, selecting an industrial common precision control tool to be put into experimental equipment for the obtained solid phase control and fluid flow speed range, developing a fluid solid phase control experiment, and obtaining the relation among solid phase output, turnover volume and capacity so as to obtain the required optimal solid phase control precision. (3) Solid phase control strategy for three-gas combined production
"three-gas commingled production" (hydrate, shallow gas, conventional gas) may be an effective way to early achieve commercial exploitation, with sand control and solid phase control being performed separately for commingled production of stratified gas. And aiming at the problem that the conventional gas field is associated with hydrate reservoir to carry out combined mining, the gas field is controlled by adopting a conventional gas field sand control method, and if the hydrate reservoir needs to be mined, the method (1) is adopted to control. Secondly, the shallow gas (free gas) associated hydrate reservoir needs to be controlled by combining the solid phase granularity of the shallow gas and the hydrate reservoir, or the grading, grading and layering design is carried out by considering the balanced liquid drainage condition of a shaft. And S1, acquiring the median particle size of the reservoir solid phase of each reservoir according to the reservoir exploration results of multilayer gas (hydrate, shallow gas and conventional gas) and determining the solid phase control strategy precision.
And S2, determining the flow velocity range of the fluid according to the flow velocity in the critical sand-carrying and the flow velocity outside the hydrate secondary generation range of different wellholes (a hydrate wellhole, a shallow gas wellhole and a conventional gas wellhole), a fluidization pipeline and the like.
And S3, selecting an industrial common precision control tool to be put into experimental equipment for the obtained solid phase control and fluid flow rate range, and developing a fluid solid phase control experiment to obtain the relation between the solid phase output and the productivity so as to obtain the required optimal solid phase control precision.
The above embodiments are only for illustrating the technical concept and features of the present invention, and the purpose thereof is to enable those skilled in the art to understand the contents of the present invention and implement the present invention accordingly, and not to limit the protection scope of the present invention accordingly. All equivalent changes or modifications made in accordance with the spirit of the present disclosure are intended to be covered by the scope of the present disclosure.
Claims (8)
1. A solid phase control method in a natural gas hydrate exploitation process is characterized by comprising the following steps:
acquiring reservoir data, calculating median particle sizes of hydrates and sand of solid phases of different reservoirs, and determining the comprehensive particle size of the solid phase of each reservoir by taking the volume ratio of the hydrates and the volume ratio of the sand in the solid phase of each reservoir as the weight of the median particle size;
determining the precision ranges of solid phase control strategies corresponding to different mining methods according to the comprehensive particle size;
determining a control flow rate range of the shaft according to the secondary generation temperature and pressure range of the hydrate in the shaft and the sand-carrying critical speed range;
and screening out an optimal solid phase control precision range and an optimal control flow rate range from the precision range and the control flow rate range through experiments according to the requirement between the sand production amount and the productivity.
2. The method of claim 1, wherein the reservoir data is obtained from exploration data and packing cores.
3. A method of solids control during natural gas hydrate production as claimed in claim 2 wherein the reservoir data includes silt particle size, hydrate saturation and formation porosity, and the hydrate volume fraction and the silt volume fraction are calculated from the hydrate saturation and formation porosity.
4. The method for controlling the solid phase in the natural gas hydrate production process according to claim 1, wherein the comprehensive particle size is calculated by
In the formula (d)g50Is the weighted median particle size of the solid phase, dh50Is the median particle size of the hydrate, ds50Is the median particle size of the silt, ShAs the proportion of hydrates in the reservoir volume, SsIs the proportion of sand in the reservoir volume.
5. A method of solid phase control in a natural gas hydrate production process as claimed in claim 1, wherein the solid phase control strategy comprises a first stage control and a second stage control, the first stage control is gravel filtration, the median particle size precision of the gravel is in the range of 5-6 times the combined particle size, the second stage control is screen filtration, and the screen aperture precision is 1-1.1 times the combined particle size.
6. The solid phase control method in the natural gas hydrate exploitation process according to claim 1, wherein the hydrate secondary generation temperature, the pressure range and the sand-carrying critical velocity range in the wellbore are input into a multi-field coupling model of a wellbore temperature field-flow field-force field-phase change field, constraint conditions are set, and the control flow velocity range is obtained by solving.
7. The method for controlling the solid phase in the natural gas hydrate exploitation process according to claim 1, wherein tools in the accuracy range are mounted on experimental equipment, a fluid solid phase control experiment is performed according to the accuracy range and the control flow rate range, a function between the sand production amount and the productivity is obtained according to an experiment result, and the optimal solid phase control accuracy and the optimal control flow rate are screened according to the function.
8. The method of claim 7, wherein the fluid solids control experiment comprises: gas and liquid fluids at different pressures, temperatures and flow rates are passed through a tool that simulates a reservoir and has a particular accuracy.
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| CN117236232A (en) * | 2023-11-15 | 2023-12-15 | 中国石油大学(华东) | Natural gas hydrate and shallow gas and deep gas combined exploitation simulation method and system |
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| 余莉;何计彬;叶成明;李小杰;李炳平;: "海域天然气水合物泥质粉砂型储层防砂砾石粒径尺寸选择", 石油钻采工艺 * |
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN117236232A (en) * | 2023-11-15 | 2023-12-15 | 中国石油大学(华东) | Natural gas hydrate and shallow gas and deep gas combined exploitation simulation method and system |
| CN117236232B (en) * | 2023-11-15 | 2024-02-20 | 中国石油大学(华东) | Natural gas hydrate and shallow gas and deep gas combined exploitation simulation method and system |
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| Publication number | Publication date |
|---|---|
| CN114776264B (en) | 2023-08-15 |
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