WO2022105945A1 - 基于深层井筒水泥浆体系模拟的控压固井方法及系统 - Google Patents
基于深层井筒水泥浆体系模拟的控压固井方法及系统 Download PDFInfo
- Publication number
- WO2022105945A1 WO2022105945A1 PCT/CN2022/072468 CN2022072468W WO2022105945A1 WO 2022105945 A1 WO2022105945 A1 WO 2022105945A1 CN 2022072468 W CN2022072468 W CN 2022072468W WO 2022105945 A1 WO2022105945 A1 WO 2022105945A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- pressure
- cement slurry
- wellbore
- bottom hole
- cementing
- Prior art date
Links
- 239000004568 cement Substances 0.000 title claims abstract description 72
- 239000002002 slurry Substances 0.000 title claims abstract description 72
- 238000000034 method Methods 0.000 title claims abstract description 52
- 238000004088 simulation Methods 0.000 title claims abstract description 39
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 50
- 230000008569 process Effects 0.000 claims abstract description 28
- 239000011148 porous material Substances 0.000 claims abstract description 22
- 238000006703 hydration reaction Methods 0.000 claims abstract description 12
- 238000006243 chemical reaction Methods 0.000 claims abstract description 8
- 239000012530 fluid Substances 0.000 claims description 26
- 238000005553 drilling Methods 0.000 claims description 12
- 230000036571 hydration Effects 0.000 claims description 11
- 238000009826 distribution Methods 0.000 claims description 5
- 239000007788 liquid Substances 0.000 claims description 4
- 238000004140 cleaning Methods 0.000 claims description 3
- 238000007711 solidification Methods 0.000 claims description 3
- 230000008023 solidification Effects 0.000 claims description 3
- 230000005465 channeling Effects 0.000 abstract description 11
- 238000011010 flushing procedure Methods 0.000 description 9
- 238000005516 engineering process Methods 0.000 description 7
- 238000010586 diagram Methods 0.000 description 6
- 238000005457 optimization Methods 0.000 description 5
- 238000002347 injection Methods 0.000 description 2
- 239000007924 injection Substances 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 125000006850 spacer group Chemical group 0.000 description 2
- 230000004580 weight loss Effects 0.000 description 2
- 230000009471 action Effects 0.000 description 1
- 238000004364 calculation method Methods 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 230000009918 complex formation Effects 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000005520 cutting process Methods 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 230000005284 excitation Effects 0.000 description 1
- 230000000750 progressive effect Effects 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 238000005406 washing Methods 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
- 239000003643 water by type Substances 0.000 description 1
Images
Classifications
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F30/00—Computer-aided design [CAD]
- G06F30/20—Design optimisation, verification or simulation
- G06F30/28—Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
-
- 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
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices, or the like
-
- 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
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F2113/00—Details relating to the application field
- G06F2113/08—Fluids
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F2119/00—Details relating to the type or aim of the analysis or the optimisation
- G06F2119/14—Force analysis or force optimisation, e.g. static or dynamic forces
Definitions
- the invention relates to the technical field of oil and gas well development, in particular to a managed pressure cementing method and system based on deep wellbore cement slurry system simulation.
- the traditional cementing technology usually uses high-density cement slurry to balance the formation pressure to prevent the occurrence of gas channeling.
- the excessively heavy cement slurry is easy to fract the formation and induce leakage accidents.
- the cementing process there are complex physical and chemical reactions in the cement slurry system in the wellbore, and the phenomenon of cement slurry hydration and weight loss will also induce the occurrence of cementing gas channeling accidents.
- the cementing process is complex, including circulating wells, casing running, cement injection, and other working conditions, resulting in the change of wellbore pressure during the cementing process, which is more likely to induce well kick, lost circulation, gas channeling and other accidents. happened. Therefore, traditional cementing technology has been difficult to meet the requirements of safe and efficient cementing in deep and complex formation conditions.
- the purpose of the present invention is to provide a managed pressure cementing method and system based on deep wellbore cement slurry system simulation, which can calculate the bottom hole pressure in real time by simulating the physical or chemical reaction process of the cement slurry system during the cementing process.
- the wellhead back pressure is controlled by adjusting the choke manifold, so that the bottom hole pressure is always maintained within the safe operation window of the formation, thereby preventing the occurrence of complex accidents such as well kick, gas channeling, and leakage, making up for the shortcomings of traditional cementing technology. .
- the present invention provides the following scheme:
- a managed pressure cementing method based on the simulation of a deep wellbore cement slurry system comprising the following steps: simulating the reaction of the wellbore cement slurry according to the basic data and cementing data of the operating well, and calculating the bottom hole pressure in the cementing process in real time according to the simulation , adjust the opening of the choke manifold to control the wellhead pressure, so that the formation pore pressure ⁇ bottom hole pressure ⁇ formation fracture pressure.
- p b is the bottom hole pressure
- p a is the wellhead back pressure
- ⁇ is the wellbore fluid density
- h is the wellbore length
- f is the annular friction coefficient
- v is the annular drilling fluid flow rate
- d w is the wellbore diameter
- d co is the outer diameter of the casing.
- it also includes the following steps: if it is a casing running operation, simulate the wellbore pressure distribution during the casing running process, and calculate the equivalent flow rate during the casing running process in is the annulus equivalent flow rate, vc is the casing speed; K c is the adhesion coefficient of drilling fluid.
- it also includes the following steps: in the case of cement injection, simulating the flow process of the liquid level of the slurry column in the wellbore, and calculating the bottom hole pressure where n is the type of injected fluid.
- h i is the length of the ith cement slurry
- ⁇ i is the hydration degree of the i th cement slurry
- ⁇ 500 is the hydration degree of the cement slurry when the strength of the cement slurry reaches the preset strength.
- the present invention also includes the following steps: if the bottom hole pressure is still lower than the formation pore pressure when the choke pipe is converged to the preset minimum opening degree, the back pressure pump is turned on to increase the wellhead pressure, so that the bottom hole pressure is increased. The pressure is greater than the formation pore pressure.
- the invention also discloses a pressure-controlled cementing system based on deep wellbore cement slurry system simulation, comprising a choke manifold, a back pressure pump connected to the choke manifold, respectively connected to the choke manifold and the A processor electrically connected to the back pressure pump, and a computer-readable medium connected to the processor, the computer-readable medium stores a preset program, and the preset program can be implemented when executed by the processor A managed pressure cementing method based on deep wellbore cement slurry system simulation as described in any of the above.
- the present invention discloses the following technical effects:
- the pressure-controlled cementing method based on the deep wellbore cement slurry system simulation of the present invention calculates the bottom hole pressure in real time by simulating the physical or chemical reaction process of the cement slurry system in the cementing process, and controls the wellhead back pressure by adjusting the choke manifold. , so that the bottom hole pressure is always maintained within the safe operation window of the formation, so as to prevent the occurrence of complex accidents such as well kick, gas channeling, and leakage, and make up for the shortcomings of traditional cementing technology.
- the controlled pressure cementing system based on the deep wellbore cement slurry system simulation of the present invention can automatically control the choke manifold and the back pressure pump according to the simulation and real-time calculation, thereby effectively ensuring the safety and reliability of the cementing process and preventing well
- the occurrence of complex accidents such as surge, gas channeling, and leakage make up for the shortcomings of traditional cementing technology.
- Fig. 1 is a schematic diagram of the well cleaning operation of the managed pressure cementing system based on the deep wellbore cement slurry system simulation of the present invention
- FIG. 2 is a schematic diagram of the casing running operation of the managed pressure cementing system based on the deep wellbore cement slurry system simulation of the present invention
- FIG. 3 is a schematic diagram of the cementing operation of the managed pressure cementing system based on the deep wellbore cement slurry system simulation of the present invention
- Fig. 4 is a schematic diagram of the waiting operation of the managed pressure cementing system based on the deep wellbore cement slurry system simulation of the present invention
- Drilling frame 1. Drilling frame; 2. Rotary control head; 3. Blowout preventer; 4. Wellbore; 5. Drilling fluid pump; 6. Drilling fluid tank; 7. Cement slurry pump; 8. Cement tank; 9. Back pressure pump; 10. Choke manifold; 11. Processor; 12. Flow meter; 13. Gas-liquid separation tank; 14. Mud pool; 15. Drill pipe; 16. Drill bit; 17. Casing; 18. Casing head; 19 , cement slurry; 22. Computer readable medium.
- the purpose of the present invention is to provide a pressure-controlled cementing method and system based on the simulation of deep wellbore cement slurry system, so that the bottom hole pressure is always maintained within the scope of the formation safety operation window, thereby preventing complex accidents such as well kick, gas channeling, and leakage
- the occurrence of wells makes up for the deficiencies of traditional cementing technology.
- Fig. 1 is the schematic diagram of the well washing operation of the managed pressure cementing system based on the simulation of the deep wellbore cement slurry system of the present invention
- Fig. 2 is the schematic diagram of the casing running operation of the managed pressure cementing system based on the simulation of the deep wellbore cement slurry system of the present invention
- Fig. 1 As shown in -2, the present invention proposes a managed pressure cementing method based on deep wellbore cement slurry system simulation, comprising the following steps:
- adjusting the opening of the choke manifold to control the wellhead pressure specifically includes:
- the opening of the choke manifold is adjusted to control the actual wellhead pressure, so that the actual wellhead pressure is less than the formation fracture pressure and greater than the formation pore pressure.
- the pressure-controlled cementing method based on the deep wellbore cement slurry system simulation of the present invention calculates the bottom hole pressure in real time by simulating the physical or chemical reaction process of the cement slurry system in the cementing process, and controls the wellhead back pressure by adjusting the choke manifold. , so that the bottom hole pressure is always maintained within the safe operation window of the formation, thereby preventing the occurrence of complex accidents such as well kick, gas channeling, and leakage, and making up for the shortcomings of traditional cementing technology.
- the wellbore 4 is a wellbore drilled into the formation.
- a blowout preventer 3 is installed on the top of the wellbore 4, the purpose of which is to close the wellbore 4 at any time when complex accidents such as well kick and lost circulation occur.
- the upper part of the blowout preventer 3 is equipped with a rotary control head 2, the purpose of which is to control the closure of the annular space between the drill pipe 15/casing 17 and the wellbore 4, and to guide the wellbore fluid from its side branches to flow into the choke Manifold 10.
- a drilling frame 1 is arranged on the upper part of the center of the wellbore to provide an operating platform for drilling/cementing workers.
- p b is the bottom hole pressure, Pa
- ⁇ is the wellbore fluid density, kg/m 3 ;
- h is the length of the wellbore, m
- f is the annular module coefficient
- v is the annular drilling fluid velocity, m/s
- d w is the diameter of the wellbore, m
- d co is the outer diameter of the casing, m.
- the bottom hole pressure is calculated by formula (1), and the bottom hole pressure is compared with the formation pore pressure and formation fracture pressure. If the bottom hole pressure is lower than the formation pore pressure, the opening of the choke pipe is reduced to make the wellhead back pressure. Elevated, the amount of increase is:
- p p is the formation pore pressure
- p f is the formation fracture pressure
- V c is the casing running speed, m/s
- K c is the adhesion coefficient of drilling fluid, dimensionless.
- the bottom hole pressure during the casing running process is obtained in real time according to the annulus equivalent flow rate, and the comparison between the bottom hole pressure and the formation pore pressure and formation fracture pressure in step S1 is repeated, and the corresponding operation, that is, if the bottom hole pressure is low
- the opening degree of the choke pipe is reduced, so that the back pressure of the wellhead increases; if the bottom hole pressure is greater than the formation fracture pressure, the opening degree of the choke pipe is increased, so that the back pressure of the well head is reduced, and the wellhead pressure is increased. Less than the formation fracture pressure and greater than the formation pore pressure.
- n is the type of injected fluid.
- step S1 the comparison of the bottom hole pressure with the formation pore pressure and the formation fracture pressure in step S1 and the corresponding operations are repeated, so that the wellhead pressure is lower than the formation fracture pressure and greater than the formation pore pressure.
- the real-time bottom hole pressure is determined by the following formula:
- h i is the length of the i-th cement slurry, m;
- ⁇ i is the hydration degree of the i-th cement slurry
- ⁇ 500 is the hydration degree of the cement slurry when the strength of the cement slurry reaches the set strength. In this embodiment, ⁇ 500 is the hydration degree of the cement slurry when the set strength is 239 Pa.
- step S1 the comparison of bottom hole pressure with formation pore pressure and formation fracture pressure in step S1 is repeated, and corresponding operations.
- the bottom hole pressure in the whole cementing process is completely simulated in real time, and the wellhead back pressure is controlled by controlling the choke manifold and the back pressure pump, so as to effectively control the bottom hole pressure within a safe range and prevent During the cementing process, complex accidents such as well kick, gas channeling, and leakage can occur.
- the simulated bottom hole pressure can be compared with the tested pressure in real time, so as to effectively judge the bottom hole situation and further ensure the safety of construction.
- the basic data of the operating well includes wellbore trajectory, wellbore structure, formation three pressure profiles, slurry column fluid parameters, formation temperature gradient, and the like.
- the present invention also proposes a managed pressure cementing system based on deep wellbore cement slurry system simulation, including a choke manifold 10 and a back pressure connected to the choke manifold 10 A pump 9, a processor 11 electrically connected to the throttling manifold 10 and the back pressure pump 9, respectively, and a computer-readable medium 22 connected to the processor 11, in the computer-readable medium 22
- a preset program and when the preset program is executed by the processor, the above-mentioned managed pressure cementing method based on deep wellbore cement slurry system simulation can be realized.
- the well flushing fluid is injected by the drilling fluid pump 5 to clean the cuttings in the wellbore.
- the processor 11 according to the simulation in the computer readable medium 11, according to the formula (1)
- the calculated bottom hole pressure, and the comparison result of bottom hole pressure, formation pore pressure and formation fracture pressure adjust the opening of the choke manifold 10, so as to control the wellhead back pressure.
- the casing is slowly run into the wellbore, which will cause excitation pressure.
- the processor 11 according to the wellbore pressure distribution simulated in the computer readable medium 22, Formula (4) calculates the equivalent flow rate, and calculates the bottom hole pressure according to the equivalent flow rate, and adjusts the opening of the choke manifold 10 or any other value according to the comparison result between the calculated bottom hole pressure, formation pore pressure and formation fracture pressure.
- the back pressure pump 9 is described, so as to adjust the back pressure of the wellhead.
- cement slurry, spacer fluid, and flushing fluid are required for cementing configuration, and are injected into the wellbore through the cement slurry pump 7 .
- the bottom hole pressure is calculated according to formula (5), and the opening of the choke manifold 10 is adjusted according to the comparison result of the calculated bottom hole pressure with the formation pore pressure and formation fracture pressure, thereby adjusting the wellhead back pressure.
- the cement slurry pump 7 stops, and the processor 11 considers the cement according to the simulation in the computer-readable medium 22 .
- the bottom hole pressure is calculated by formula (5), and the opening of the choke manifold 10 or the The back pressure pump 9 is used to adjust the back pressure of the wellhead.
Abstract
Description
Claims (7)
- 一种基于深层井筒水泥浆体系模拟的控压固井方法,其特征在于,包括如下步骤:根据作业井的基础数据和固井数据,模拟井筒水泥浆的反应,根据模拟实时计算固井过程中的井底压力,调节节流管汇的开度以控制井口压力,从而使地层孔隙压力<井底压力<地层破裂压力。
- 根据权利要求1-5任一项中所述的基于深层井筒水泥浆体系模拟的控压固井方法,其特征在于,还包括如下步骤:若节流管汇开到预设最小开度时井底压力仍小于地层孔隙压力,则开启回压泵以使井口压力增大,从而使井底压力大于地层孔隙压力。
- 一种基于深层井筒水泥浆体系模拟的控压固井系统,其特征在于,包括节流管汇,与所述节流管汇连接的回压泵,分别与所述节流管汇和所述回压泵电性连接的处理器,以及与所述处理器连接的计算机可读介质,所述计算机可读介质中存有预设程序,该预设程序被所述处理器执行时能够实现如权利要求1-6任一项中所述的基于深层井筒水泥浆体系模拟的控压固井方法。
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
GB2209895.8A GB2617631A (en) | 2020-11-18 | 2022-01-18 | Method and system for managed pressure well cementing based on deep wellbore cement slurry system simulation |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
CN202011292610.5 | 2020-11-18 | ||
CN202011292610.5A CN112417778A (zh) | 2020-11-18 | 2020-11-18 | 基于深层井筒水泥浆体系模拟的控压固井方法及系统 |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2022105945A1 true WO2022105945A1 (zh) | 2022-05-27 |
Family
ID=74831962
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/CN2022/072468 WO2022105945A1 (zh) | 2020-11-18 | 2022-01-18 | 基于深层井筒水泥浆体系模拟的控压固井方法及系统 |
Country Status (3)
Country | Link |
---|---|
CN (1) | CN112417778A (zh) |
GB (1) | GB2617631A (zh) |
WO (1) | WO2022105945A1 (zh) |
Families Citing this family (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN112417778A (zh) * | 2020-11-18 | 2021-02-26 | 中国石油大学(华东) | 基于深层井筒水泥浆体系模拟的控压固井方法及系统 |
CN113006769B (zh) * | 2021-03-17 | 2022-07-26 | 中国石油大学(华东) | 一种复杂压力体系地层智能压井方法及装置 |
CN113216940B (zh) * | 2021-04-27 | 2022-04-15 | 中国平煤神马能源化工集团有限责任公司 | 一种多点位岩层孔隙压力测试方法及系统 |
CN116163673B (zh) * | 2023-04-25 | 2023-07-04 | 中国石油大学(华东) | 一种用于深水浅层梯度固井循环井口微压控制装置及方法 |
Citations (7)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20040065440A1 (en) * | 2002-10-04 | 2004-04-08 | Halliburton Energy Services, Inc. | Dual-gradient drilling using nitrogen injection |
CN101710468A (zh) * | 2009-12-16 | 2010-05-19 | 西南石油大学 | 钻井模拟器压力控制模拟方法 |
CN106285554A (zh) * | 2016-09-07 | 2017-01-04 | 中国石油大学(华东) | 用于固井阶段的井筒压力控制系统及方法 |
CN108119074A (zh) * | 2018-01-04 | 2018-06-05 | 中国石油大学(华东) | 自反馈两相体系钻井液混合系统及混合钻井液的方法 |
CN108222865A (zh) * | 2018-01-04 | 2018-06-29 | 中国石油大学(华东) | 自反馈三相体系钻井液混合系统及混合钻井液的方法 |
CN111396025A (zh) * | 2020-03-19 | 2020-07-10 | 成都维泰油气能源技术有限公司 | 控压钻井智能钻进控制、钻进异常识别和处理方法及系统 |
CN112417778A (zh) * | 2020-11-18 | 2021-02-26 | 中国石油大学(华东) | 基于深层井筒水泥浆体系模拟的控压固井方法及系统 |
-
2020
- 2020-11-18 CN CN202011292610.5A patent/CN112417778A/zh active Pending
-
2022
- 2022-01-18 GB GB2209895.8A patent/GB2617631A/en active Pending
- 2022-01-18 WO PCT/CN2022/072468 patent/WO2022105945A1/zh active Application Filing
Patent Citations (7)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20040065440A1 (en) * | 2002-10-04 | 2004-04-08 | Halliburton Energy Services, Inc. | Dual-gradient drilling using nitrogen injection |
CN101710468A (zh) * | 2009-12-16 | 2010-05-19 | 西南石油大学 | 钻井模拟器压力控制模拟方法 |
CN106285554A (zh) * | 2016-09-07 | 2017-01-04 | 中国石油大学(华东) | 用于固井阶段的井筒压力控制系统及方法 |
CN108119074A (zh) * | 2018-01-04 | 2018-06-05 | 中国石油大学(华东) | 自反馈两相体系钻井液混合系统及混合钻井液的方法 |
CN108222865A (zh) * | 2018-01-04 | 2018-06-29 | 中国石油大学(华东) | 自反馈三相体系钻井液混合系统及混合钻井液的方法 |
CN111396025A (zh) * | 2020-03-19 | 2020-07-10 | 成都维泰油气能源技术有限公司 | 控压钻井智能钻进控制、钻进异常识别和处理方法及系统 |
CN112417778A (zh) * | 2020-11-18 | 2021-02-26 | 中国石油大学(华东) | 基于深层井筒水泥浆体系模拟的控压固井方法及系统 |
Non-Patent Citations (1)
Title |
---|
SUN, BAOJIANG, SHI YOU ZUAN TAN JI SHU: "Research Development and Outlook for Managed Pressure Cementing Technology", PETROLEUM DRILLING TECHNIQUES, vol. 47, no. 3, 1 January 2019 (2019-01-01), pages 56 - 61, XP055931391, ISSN: 1001-0890, DOI: 10.11911/syztjs.2019066 * |
Also Published As
Publication number | Publication date |
---|---|
CN112417778A (zh) | 2021-02-26 |
GB202209895D0 (en) | 2022-08-17 |
GB2617631A (en) | 2023-10-18 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
WO2022105945A1 (zh) | 基于深层井筒水泥浆体系模拟的控压固井方法及系统 | |
CN101139911B (zh) | 注气稳压钻井方法 | |
CN101070755B (zh) | 一种基于双梯度的控制压力钻井装置 | |
RU2341654C2 (ru) | Способ и система циркуляции текучей среды в системе скважин | |
RU2520201C1 (ru) | Способ поддержания давления в скважине | |
US6571873B2 (en) | Method for controlling bottom-hole pressure during dual-gradient drilling | |
CN102828712B (zh) | 用于施加井口回压的双节流控制泥浆泵分流管汇及其方法 | |
CN203756087U (zh) | 一种平衡压力钻井控压装置 | |
CN110118069A (zh) | 一种超深井钻井压力控制设备及操作方法 | |
CN201059187Y (zh) | 一种基于双梯度的控制压力钻井装置 | |
CN105672927A (zh) | 一种气体钻井井喷后的压井方法 | |
CN106368607B (zh) | 利用深水双梯度钻井中实施压井的系统实施压井的方法 | |
Saponja | Challenges with jointed-pipe underbalanced operations | |
Kotow et al. | Riserless Drilling with Casing: A New Paradigm for Deepwater Well Design | |
Martin | Managed pressure drilling techniques and tools | |
Wang et al. | Development and application of wellbore heat transfer model considering variable mass flow | |
Yan et al. | Application of fine managed pressure drilling technique in complex wells with both blowout and lost circulation risks | |
AU2019202100B2 (en) | Drilling fluid density segmented regulation device | |
CN108915595B (zh) | 深水钻井井控管理方法 | |
Falk et al. | Well control when drilling with a partly-evacuated marine drilling riser | |
Santos | Important aspects of well control for horizontal drilling including deepwater situations | |
RU2148698C1 (ru) | Способ вскрытия продуктивного газоносного пласта бурением | |
US20120103626A1 (en) | A well completion method | |
CN111028648A (zh) | 一种深水钻井深层气侵模拟试验系统及方法 | |
CN115455740A (zh) | 控压钻井与固井作业环节衔接中的井口压力动态调控方法 |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
121 | Ep: the epo has been informed by wipo that ep was designated in this application |
Ref document number: 22724393 Country of ref document: EP Kind code of ref document: A1 |
|
ENP | Entry into the national phase |
Ref document number: 202209895 Country of ref document: GB Kind code of ref document: A Free format text: PCT FILING DATE = 20220118 |
|
NENP | Non-entry into the national phase |
Ref country code: DE |
|
122 | Ep: pct application non-entry in european phase |
Ref document number: 22724393 Country of ref document: EP Kind code of ref document: A1 |