CA2486235A1 - An automatic control system and method for bottom hole pressure in the underbalance drilling - Google Patents
An automatic control system and method for bottom hole pressure in the underbalance drilling Download PDFInfo
- Publication number
- CA2486235A1 CA2486235A1 CA002486235A CA2486235A CA2486235A1 CA 2486235 A1 CA2486235 A1 CA 2486235A1 CA 002486235 A CA002486235 A CA 002486235A CA 2486235 A CA2486235 A CA 2486235A CA 2486235 A1 CA2486235 A1 CA 2486235A1
- Authority
- CA
- Canada
- Prior art keywords
- data
- bhp
- pressure
- data processing
- drilling
- 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.)
- Granted
Links
- 238000000034 method Methods 0.000 title claims abstract 47
- 238000005553 drilling Methods 0.000 title claims abstract 37
- 239000012530 fluid Substances 0.000 claims abstract 13
- 238000012544 monitoring process Methods 0.000 claims abstract 3
- 239000007788 liquid Substances 0.000 claims 20
- 230000003068 static effect Effects 0.000 claims 10
- 238000004891 communication Methods 0.000 claims 3
- 230000005540 biological transmission Effects 0.000 claims 2
- 238000006243 chemical reaction Methods 0.000 claims 2
- 238000001514 detection method Methods 0.000 claims 2
- 230000001960 triggered effect Effects 0.000 claims 2
- 230000001105 regulatory effect Effects 0.000 claims 1
- 238000009966 trimming Methods 0.000 claims 1
- 238000005516 engineering process Methods 0.000 abstract 1
- 230000007246 mechanism Effects 0.000 abstract 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
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/08—Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
- E21B21/085—Underbalanced techniques, i.e. where borehole fluid pressure is below formation pressure
Abstract
This invention provides an automatic control system and method fox bottom bole pressure (BHP) in the underbalance drilling. It relates to a computer automatic control technology. The automatic control system according to the invention includes a processing module for the BHP based on the mechanisms of hydraulics. The BHP in the underbalance drilling is calculated from the acquired standpipe pressure (SPP), the calculated circulating pressure loss in the drilling tools, drill bit pressure drop and the fluid column pressure in the drill string. The resulting BHP is then compared with the set pressure value of the system. In case that the BHP is higher or lower than the set pressure, an instruction to regulate throttle valve opening will be issued in order to bring the BHP back to the set pressure range and complete BHP monitoring and control, The automatic control system and method according to the invention enable real-time tracking of the changes in BHP and achieve accurate and timely adjustment and control of BHP. The automatic control system and method improve the level of automation in the underbalance drilling process, and also enhance the reliability and safety in the underbalance drilling operation, which have wide foreground for application.
Claims (14)
1. An automatic control system for bottom hole pressure (BHP) in the underbalance drilling (UBD), comprising a data acquisition unit, a data processing unit, a control and execution unit, and a data conversion and transmission unit, characterized by:
(1) the data acquisition unit comprising a dynamic modeling data acquisition module and a static data input module, the dynamic modeling data acquisition module including pressure sensors provided in drilling operation system to collect standpipe pressure and casing pressure, and pump stroke sensors to collect pump strokes of the mud pump, the static data input module for inputting many parameters including borehole structure, drilling tool configuration, mud property and well depth through man-machine interface;
(2) the data processing unit comprising a processing module for the BHP in the underbalance drilling, the module processing the parameters including all the above-mentioned dynamic and static data, and the BHP in the underbalance drilling calculated from the acquired standpipe pressure (SPP), the calculated circulating pressure loss in the drilling tools, drill bit pressure drop and the fluid column pressure in the drill string, then the resulting BHP compared with the set pressure of the system, and an instruction to regulate throttle valve opening issued when the BHP is higher or lower than the set pressure;
(3) the control and execution unit including a throttle valve and throttle valve control module, the throttle valve control module sending a control signal to the throttle valve to control the opening thereof whein receiving an instruction to control throttle valve opening from data processing unit, so as to limit the BHP within the set pressure range in real time;
(4) the data conversion and transmission unit for transmitting the dynamic modeling data and static input data in the underbalance drilling operation acquired in real time by the above mentioned data acquisition unit to data processing unit, or transmitting the instruction of regulating throttle valve opening to the control and execution unit.
(1) the data acquisition unit comprising a dynamic modeling data acquisition module and a static data input module, the dynamic modeling data acquisition module including pressure sensors provided in drilling operation system to collect standpipe pressure and casing pressure, and pump stroke sensors to collect pump strokes of the mud pump, the static data input module for inputting many parameters including borehole structure, drilling tool configuration, mud property and well depth through man-machine interface;
(2) the data processing unit comprising a processing module for the BHP in the underbalance drilling, the module processing the parameters including all the above-mentioned dynamic and static data, and the BHP in the underbalance drilling calculated from the acquired standpipe pressure (SPP), the calculated circulating pressure loss in the drilling tools, drill bit pressure drop and the fluid column pressure in the drill string, then the resulting BHP compared with the set pressure of the system, and an instruction to regulate throttle valve opening issued when the BHP is higher or lower than the set pressure;
(3) the control and execution unit including a throttle valve and throttle valve control module, the throttle valve control module sending a control signal to the throttle valve to control the opening thereof whein receiving an instruction to control throttle valve opening from data processing unit, so as to limit the BHP within the set pressure range in real time;
(4) the data conversion and transmission unit for transmitting the dynamic modeling data and static input data in the underbalance drilling operation acquired in real time by the above mentioned data acquisition unit to data processing unit, or transmitting the instruction of regulating throttle valve opening to the control and execution unit.
2. The automatic control system of claim 1, wherein the value calculated by deducting the circulating pressure loss in the drilling tools and drill bit pressure drop from the sum of the standpipe pressure (SPP) and the fluid column pressure in the drilling tools is regarded as the BHP during drilling operation in the data processing unit.
3. The automatic control. system of claim 1, wherein the data acquisition unit includes a H2S concentration detection sensor;
the data processing unit includes an alarm control module for the presence of excessive H2S, and the data acquisition unit inputs the dynamic data of H2S concentration into the alarm control module for the presence of excessive H2S, which compares the actually detected concentration with the set concentration of the system and sends an instruction to the control and execution unit to trigger the alarm if the actually detected concentration is higher than the set value;
the control and execution unit includes an alarm for the presence of excessive H2S, and the alarm will be triggered upon receipt of such instruction from the data processing unit.
the data processing unit includes an alarm control module for the presence of excessive H2S, and the data acquisition unit inputs the dynamic data of H2S concentration into the alarm control module for the presence of excessive H2S, which compares the actually detected concentration with the set concentration of the system and sends an instruction to the control and execution unit to trigger the alarm if the actually detected concentration is higher than the set value;
the control and execution unit includes an alarm for the presence of excessive H2S, and the alarm will be triggered upon receipt of such instruction from the data processing unit.
4. The automatic control system of claim 1, wherein the data acquisition unit includes flammable gas concentration detection sensor;
the data processing unit includes igniter control module, and the data acquisition unit inputs the dynamic data of flammable gas concentration into the igniter control module, which compares the actually detected concentration with the set concentration of the system and sends an instruction of the presence of excessive flammable gas to the control and execution unit if the actually detected concentration is higher than the set value;
the control and execution unit includes an igniter provided on the igniting pipeline, and the igniter will automatically ignite and burn flammable gas when it receives the instruction of the presence of excessive flammable gas from the data processing unit.
the data processing unit includes igniter control module, and the data acquisition unit inputs the dynamic data of flammable gas concentration into the igniter control module, which compares the actually detected concentration with the set concentration of the system and sends an instruction of the presence of excessive flammable gas to the control and execution unit if the actually detected concentration is higher than the set value;
the control and execution unit includes an igniter provided on the igniting pipeline, and the igniter will automatically ignite and burn flammable gas when it receives the instruction of the presence of excessive flammable gas from the data processing unit.
5. The automatic control system of claim 1, wherein the data acquisition unit includes a liquid level gauge for measuring the liquid level of the skimming tank;
the data processing unit includes mud-dumping pump control module, and the data acquisition unit inputs the dynamic data of the liquid level of the skimming tank into the mud-dumping pump control module, which compares the actually acquired liquid level data with the set value and sends an instruction to the control and execution unit to start the mud-dumping pump if the actually acquired liquid level is higher than the set value;
the control and execution unit includes the mud-dumping pump provided on the skimming tank, the mud-dumping pump will be started to pump the drilling fluid in the trimming tank into the circulating tank of drilling fluid to maintain the normal operation of the underbalance circulating system of drilling fluid upon receipt of the instruction to start the mud-dumping pump from the data processing unit.
the data processing unit includes mud-dumping pump control module, and the data acquisition unit inputs the dynamic data of the liquid level of the skimming tank into the mud-dumping pump control module, which compares the actually acquired liquid level data with the set value and sends an instruction to the control and execution unit to start the mud-dumping pump if the actually acquired liquid level is higher than the set value;
the control and execution unit includes the mud-dumping pump provided on the skimming tank, the mud-dumping pump will be started to pump the drilling fluid in the trimming tank into the circulating tank of drilling fluid to maintain the normal operation of the underbalance circulating system of drilling fluid upon receipt of the instruction to start the mud-dumping pump from the data processing unit.
6. The automatic control system of claim 1, wherein the data acquisition unit includes a liquid level gauge for measuring the liquid level of the mud tank;
the data processing unit includes well kick and lost of well alarm control module, and the data acquisition unit inputs the dynamic data of the liquid level of the mud tank into the well kick and lost of well alarm control module, which compares the actually acquired liquid level with the liquid level for the last time interval and sends an alarm triggering instruction to the control and execution unit if the fluctuation value of the liquid level is higher than the set valve;
the control and execution unit includes well kick and lost of well alarm, which will he triggered upon receipt of such instruction from the data processing unit.
the data processing unit includes well kick and lost of well alarm control module, and the data acquisition unit inputs the dynamic data of the liquid level of the mud tank into the well kick and lost of well alarm control module, which compares the actually acquired liquid level with the liquid level for the last time interval and sends an alarm triggering instruction to the control and execution unit if the fluctuation value of the liquid level is higher than the set valve;
the control and execution unit includes well kick and lost of well alarm, which will he triggered upon receipt of such instruction from the data processing unit.
7. The automatic control system, of claim 1, wherein said automatic control system further includes system configuration display unit, which includes a data display module and a communication module, and the system configuration display unit exchanges data with the data processing unit through communication module, and wherein after the original parameters of the static data are transmitted to the data processing unit through communication module and its connection, the system configuration display unit initializes those static data including borehole structure, drilling tool configuration, mud property and well depth, and transmits updated data including well depth and drilling fluid property to the data processing unit at any time depending on drilling status, while drilling monitoring video, onsite operation data and the resulting data transmitted back from the data processing unit are displayed in a dynamic way and are memorized.
8. An automatic control method for bottoms hole pressure (BHP) in the underbalance drilling, said method comprising a data acquisition process, a data processing process and a control and execution process, wherein, (1) the data acquisition process includes: inputting static data and conducting real-time acquisition of the dynamic modeling data of standpipe pressure (SPP), casing pressure (CP) and mud pump stroke during drilling operation, and transmitting the acquired data to data processing process;
(2) the data processing process includes processing the static data including borehole structure, drilling tool configuration and mud property as well as the dynamic data acquired from data acquisition process, and calculating the BHP in the underbalance drilling upon the acquired standpipe pressure (SPP) and the calculated circulating pressure loss in the drilling tools and drill bit pressure drop as well as the fluid column pressure in the drill string, and issuing an instruction to decrease throttle valve opening to increase casing pressure value when the resulting BHP is lower than (the set pressure value - the error allowance), recalculating the BHP upon the newly changed standpipe pressure (SPP) and the dynamic anal static data mentioned above after a delay period for pressure propagation, then comparing the resulting BHP with the set value to determine if it is necessary to adjust the throttle valve opening again, and then continuing this process until the BHP is within the range of (the set pressure value ~
the error allowance); alternatively, issuing an instruction to increase throttle valve opening to reduce casing pressure value when the BHP is higher than (the set pressure value + the error allowance), recalculating the BHP upon the newly changed standpipe pressure (SPP) and other data after a delay period for pressure propagation, then comparing the resulting BHP with the set pressure value to determine if it is necessary to adjust the throttle valve opening again, and then continuing this process until the BHP is within the range of (the set pressure value ~ the error allowance);
(3) the control and execution process includes: sending control signals to electric control throttle valve and adjusting throttle valve opening upon receipt of the instruction to control throttle valve opening from data processing process, so as to limit the BHP within the set pressure range in real time.
(2) the data processing process includes processing the static data including borehole structure, drilling tool configuration and mud property as well as the dynamic data acquired from data acquisition process, and calculating the BHP in the underbalance drilling upon the acquired standpipe pressure (SPP) and the calculated circulating pressure loss in the drilling tools and drill bit pressure drop as well as the fluid column pressure in the drill string, and issuing an instruction to decrease throttle valve opening to increase casing pressure value when the resulting BHP is lower than (the set pressure value - the error allowance), recalculating the BHP upon the newly changed standpipe pressure (SPP) and the dynamic anal static data mentioned above after a delay period for pressure propagation, then comparing the resulting BHP with the set value to determine if it is necessary to adjust the throttle valve opening again, and then continuing this process until the BHP is within the range of (the set pressure value ~
the error allowance); alternatively, issuing an instruction to increase throttle valve opening to reduce casing pressure value when the BHP is higher than (the set pressure value + the error allowance), recalculating the BHP upon the newly changed standpipe pressure (SPP) and other data after a delay period for pressure propagation, then comparing the resulting BHP with the set pressure value to determine if it is necessary to adjust the throttle valve opening again, and then continuing this process until the BHP is within the range of (the set pressure value ~ the error allowance);
(3) the control and execution process includes: sending control signals to electric control throttle valve and adjusting throttle valve opening upon receipt of the instruction to control throttle valve opening from data processing process, so as to limit the BHP within the set pressure range in real time.
9. The method of claim 8, wherein the value calculated by deducting the circulating pressure loss in the drilling tools and drill bit pressure drop from the sum of the standpipe pressure (SPP) and the fluid column pressure in the drilling tools is regarded as the BHP during drilling operation in the data processing process.
10. The method of claim 8, wherein the data acquisition process includes the step of collecting the dynamic modeling data of H2S concentration;
the data processing process includes the steps of comparing the H2S concentration actually acquired in data acquisition process with the set concentration value, and issuing an alarm triggering instruction of the actually acquired concentration is higher than the set concentration value;
the control and execution process includes the step of triggering an alarm upon receipt of such instruction from data processing process.
the data processing process includes the steps of comparing the H2S concentration actually acquired in data acquisition process with the set concentration value, and issuing an alarm triggering instruction of the actually acquired concentration is higher than the set concentration value;
the control and execution process includes the step of triggering an alarm upon receipt of such instruction from data processing process.
11. The method of claim 8, wherein the data acquisition process includes the step of collecting the dynamic modeling data of flammable gas concentration;
the data processing process includes the steps of comparing the flammable gas concentration actually acquired in data acquisition process with the set concentration value, and issuing an instruction of the presence of excessive flammable gas if the actually acquired concentration is higher than the set concentration value;
the control and execution process includes the step of trigging of igniter to burn flammable gas upon receipt of the instruction of the presence of excessive flammable gas from data processing process.
the data processing process includes the steps of comparing the flammable gas concentration actually acquired in data acquisition process with the set concentration value, and issuing an instruction of the presence of excessive flammable gas if the actually acquired concentration is higher than the set concentration value;
the control and execution process includes the step of trigging of igniter to burn flammable gas upon receipt of the instruction of the presence of excessive flammable gas from data processing process.
12. The method of claim 8, wherein the data acquisition process includes the step of collecting the dynamic modeling data of the liquid level of the skimming tank;
the data processing process includes the steps of comparing the liquid level of the skimming tank actually acquired in data acquisition process with the set liquid level, and issuing an instruction to start mud-dumping pump if the actually acquired liquid level is higher than the set liquid level;
the control and execution process includes the steps of starting the mud-dumping pump to pump the drilling fluid in the skimming tank into the circulating tank of drilling fluid so as to maintain the normal operation of underbalance drilling fluid circulation system upon receipt of the instruction to start the mud-dumping pump from data processing process.
the data processing process includes the steps of comparing the liquid level of the skimming tank actually acquired in data acquisition process with the set liquid level, and issuing an instruction to start mud-dumping pump if the actually acquired liquid level is higher than the set liquid level;
the control and execution process includes the steps of starting the mud-dumping pump to pump the drilling fluid in the skimming tank into the circulating tank of drilling fluid so as to maintain the normal operation of underbalance drilling fluid circulation system upon receipt of the instruction to start the mud-dumping pump from data processing process.
13. The method of claim 8, wherein the data acquisition process includes the step of collecting the dynamic modeling data of the liquid level of the mud tank;
the data processing process includes the steps of comparing the actually acquired liquid level data of the mud tank with the liquid level data for the last time interval and issuing an alarm triggering instruction if the fluctuation value of the liquid level is higher than the set value;
the control and execution process includes the step of triggering of well kick and cost of well alarm upon receipt of such instruction from data processing unit.
the data processing process includes the steps of comparing the actually acquired liquid level data of the mud tank with the liquid level data for the last time interval and issuing an alarm triggering instruction if the fluctuation value of the liquid level is higher than the set value;
the control and execution process includes the step of triggering of well kick and cost of well alarm upon receipt of such instruction from data processing unit.
14. The method of claim 8, further comprising a system configuration display process, wherein the static data acquired from data processing process are initialized, and updated data including well depth and drilling fluid property are transmitted to data processing process at any time depending on drilling status, while the resulting data are transmitted back from data processing process and drilling monitoring video and onsite operation data are displayed in a dynamic way.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CNB2003101034331A CN100353027C (en) | 2003-10-31 | 2003-10-31 | Under balance drilling bottom pressure automatic control system and method |
| CN200310103433.1 | 2003-10-31 |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2486235A1 true CA2486235A1 (en) | 2005-04-30 |
| CA2486235C CA2486235C (en) | 2012-09-25 |
Family
ID=34473853
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2486235A Active CA2486235C (en) | 2003-10-31 | 2004-10-28 | An automatic control system and method for bottom hole pressure in the underbalance drilling |
Country Status (3)
| Country | Link |
|---|---|
| US (1) | US7158886B2 (en) |
| CN (1) | CN100353027C (en) |
| CA (1) | CA2486235C (en) |
Cited By (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN104929620A (en) * | 2014-03-21 | 2015-09-23 | 韩文峰 | Drilling-fluid on-line extreme pressure lubricity tester |
| CN110886585A (en) * | 2019-12-02 | 2020-03-17 | 中国石油集团西部钻探工程有限公司 | Automatic throttle control device for back pressure compensation in drilling operation and use method thereof |
| CN113738339A (en) * | 2020-06-17 | 2021-12-03 | 中国石油天然气股份有限公司 | Control method and device for wellhead blowout making system in oilfield operation |
Families Citing this family (77)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US8955619B2 (en) * | 2002-05-28 | 2015-02-17 | Weatherford/Lamb, Inc. | Managed pressure drilling |
| CA2436134C (en) * | 2003-07-25 | 2009-10-20 | Javed Shah | Method of controlling a well experiencing gas kicks |
| US7836973B2 (en) | 2005-10-20 | 2010-11-23 | Weatherford/Lamb, Inc. | Annulus pressure control drilling systems and methods |
| US8490719B2 (en) * | 2006-10-23 | 2013-07-23 | M-I L.L.C. | Method and apparatus for controlling bottom hole pressure in a subterranean formation during rig pump operation |
| US9435162B2 (en) | 2006-10-23 | 2016-09-06 | M-I L.L.C. | Method and apparatus for controlling bottom hole pressure in a subterranean formation during rig pump operation |
| CA2840725C (en) | 2006-11-07 | 2015-12-29 | Charles R. Orbell | Method of pressure testing a riser string |
| US7706980B2 (en) * | 2007-02-01 | 2010-04-27 | Bp Corporation North America Inc. | Blowout preventer testing system and method |
| US7827128B1 (en) | 2007-05-11 | 2010-11-02 | Aol Advertising Inc. | System identification, estimation, and prediction of advertising-related data |
| CN101737018B (en) * | 2008-11-26 | 2013-09-18 | 西部钻探克拉玛依钻井工艺研究院 | Real-time monitoring method and device of underbalanced drilling well bottom pressure |
| US8281875B2 (en) | 2008-12-19 | 2012-10-09 | Halliburton Energy Services, Inc. | Pressure and flow control in drilling operations |
| NO338750B1 (en) | 2009-03-02 | 2016-10-17 | Drilltronics Rig Systems As | Method and system for automated drilling process control |
| GB2473672B (en) | 2009-09-22 | 2013-10-02 | Statoilhydro Asa | Control method and apparatus for well operations |
| US20110155466A1 (en) * | 2009-12-28 | 2011-06-30 | Halliburton Energy Services, Inc. | Varied rpm drill bit steering |
| GB2478119A (en) * | 2010-02-24 | 2011-08-31 | Managed Pressure Operations Llc | A drilling system having a riser closure mounted above a telescopic joint |
| US8820405B2 (en) | 2010-04-27 | 2014-09-02 | Halliburton Energy Services, Inc. | Segregating flowable materials in a well |
| US8201628B2 (en) | 2010-04-27 | 2012-06-19 | Halliburton Energy Services, Inc. | Wellbore pressure control with segregated fluid columns |
| EP2582912A4 (en) * | 2010-06-15 | 2017-12-13 | Halliburton Energy Services, Inc. | Annulus pressure setpoint correction using real time pressure while drilling measurements |
| US8240398B2 (en) | 2010-06-15 | 2012-08-14 | Halliburton Energy Services, Inc. | Annulus pressure setpoint correction using real time pressure while drilling measurements |
| CN102454372A (en) * | 2010-10-19 | 2012-05-16 | 中国石油化工集团公司 | Shaft pressure management system and method |
| CN102174887B (en) * | 2011-01-05 | 2014-03-12 | 中国海洋石油总公司 | Device for measuring annulus flow between sea bottom marine riser and drill column by using ultrasonic waves |
| US9249638B2 (en) | 2011-04-08 | 2016-02-02 | Halliburton Energy Services, Inc. | Wellbore pressure control with optimized pressure drilling |
| MY168333A (en) * | 2011-04-08 | 2018-10-30 | Halliburton Energy Services Inc | Automatic standpipe pressure control in drilling |
| US9080407B2 (en) | 2011-05-09 | 2015-07-14 | Halliburton Energy Services, Inc. | Pressure and flow control in drilling operations |
| EP2729661A4 (en) * | 2011-07-05 | 2015-12-02 | Halliburton Energy Services Inc | Well drilling methods with automated response to event detection |
| BR112014004638A2 (en) | 2011-09-08 | 2017-03-14 | Halliburton Energy Services Inc | method for maintaining a desired temperature at a location in a well, and, well system |
| US9085961B2 (en) * | 2011-10-19 | 2015-07-21 | Keldon Ehalt | Well cellar high fluid level alarm |
| US9725974B2 (en) | 2011-11-30 | 2017-08-08 | Halliburton Energy Services, Inc. | Use of downhole pressure measurements while drilling to detect and mitigate influxes |
| CN103775011B (en) * | 2012-10-22 | 2016-10-19 | 中国石油化工股份有限公司 | wellbore pressure control system and control method |
| CN104100259B (en) * | 2013-04-03 | 2017-02-15 | 中国石油天然气集团公司 | Method and device for stabilizing well wall in fine managed pressure drilling |
| CN103206180B (en) * | 2013-04-12 | 2015-11-18 | 中联煤层气国家工程研究中心有限责任公司 | Control the system and method for the bottom pressure decrease speed of coal bed gas well |
| CN104634375B (en) * | 2013-11-08 | 2017-02-01 | 常州市计量测试技术研究所 | Full-automatic geotechnical instrument mechanical performance detection method |
| GB2521374A (en) | 2013-12-17 | 2015-06-24 | Managed Pressure Operations | Drilling system and method of operating a drilling system |
| GB2521373A (en) | 2013-12-17 | 2015-06-24 | Managed Pressure Operations | Apparatus and method for degassing drilling fluid |
| CN103821498A (en) * | 2014-03-13 | 2014-05-28 | 中国水电顾问集团中南勘测设计研究院有限公司 | Observation instrument embedded blockage system for drilling hole high-pressure packer test |
| CN105089609B (en) * | 2014-04-18 | 2017-09-08 | 中国石油化工集团公司 | Method for controlling wellbore pressure |
| CN105089527B (en) * | 2014-04-18 | 2017-12-12 | 中国石油化工集团公司 | For controlling the device and method of wellbore pressure |
| CN103939093A (en) * | 2014-05-06 | 2014-07-23 | 西安石油大学 | Visual physical simulation device under condition of complex hydrocarbon reservoir real core well network |
| MX2017000812A (en) * | 2014-08-22 | 2017-05-04 | Halliburton Energy Services Inc | Downhole pressure sensing device for open-hole operations. |
| CN104481436B (en) * | 2014-12-05 | 2017-05-10 | 中国石油天然气集团公司 | Method and system for regulating precision pressure-control well drilling throttle valve |
| CN104763407B (en) * | 2015-02-08 | 2017-06-23 | 东北石油大学 | Under balance pressure drilling broken rock analogue experiment installation and its analogue experiment method |
| CN106014387A (en) * | 2016-05-23 | 2016-10-12 | 中国石油集团川庆钻探工程有限公司 | Bottom hole pressure real-time prediction and control method |
| GB2551141B (en) | 2016-06-07 | 2020-05-13 | Equinor Energy As | Method and system for managed pressure drilling |
| CN106444563A (en) * | 2016-12-12 | 2017-02-22 | 中国石油集团川庆钻探工程有限公司 | Safety guarantee system applicable to gas drilling |
| CN106894786B (en) * | 2017-03-31 | 2022-11-11 | 西安特耐测控仪器有限公司 | Low-permeability reservoir water shutoff profile control online monitoring system and method |
| CN107605427A (en) * | 2017-10-27 | 2018-01-19 | 烟台杰瑞石油装备技术有限公司 | A kind of remote auto discharge capacity and Density Automatic Control System |
| CN108825155B (en) * | 2018-08-09 | 2024-03-29 | 上海万维亿通装备制造有限公司 | Method for removing blockage outside underground unbalanced jet dredging vacuum suction sleeve |
| WO2020028994A1 (en) * | 2018-08-10 | 2020-02-13 | Rgl Reservoir Management Inc. | Nozzle for steam injection and steam choking |
| CN109458171B (en) * | 2018-10-23 | 2022-04-22 | 西南石油大学 | Novel method for measuring stratum leakage pressure with narrow safe density window |
| CN109441432B (en) * | 2018-10-23 | 2022-04-22 | 西南石油大学 | Method for detecting circulating pressure loss of stratum drilling shaft with narrow safety density window |
| CN109538141B (en) * | 2018-11-27 | 2020-09-29 | 重庆科技学院 | Embedded automatic control device for drilling throttle manifold |
| CN109488286B (en) * | 2018-12-03 | 2022-03-11 | 西南石油大学 | Method for monitoring underground multi-point pressure measurement overflow of oil and gas well |
| CN109812710B (en) * | 2019-01-28 | 2020-10-27 | 新昌县陆恒机械有限公司 | Oil field pipeline supercharging device |
| CN109630048A (en) * | 2019-02-22 | 2019-04-16 | 西南石油大学 | A kind of controlled pressure drilling auxiliary device |
| CN110055967B (en) * | 2019-03-14 | 2024-04-02 | 姚燕明 | Slurry control system and control method for ultra-deep underground diaphragm wall |
| CN110145283B (en) * | 2019-04-17 | 2024-03-26 | 中国石油天然气股份有限公司 | Underground flow automatic control method and device without flowmeter |
| CN110130849B (en) * | 2019-05-08 | 2023-12-19 | 北京石油机械有限公司 | Blowout preventer control system based on Internet of things |
| CN110388189B (en) * | 2019-05-15 | 2024-03-19 | 西南石油大学 | Intelligent throttling well-killing method and device for overflow of high-temperature high-pressure deep well drilling |
| CN110847834A (en) * | 2019-12-02 | 2020-02-28 | 中国石油集团西部钻探工程有限公司 | Method for controlling bottom hole pressure stability in process of replacing rotary assembly |
| CN111577240B (en) * | 2020-04-24 | 2023-07-14 | 洲际海峡能源科技有限公司 | Wireless centralized control system of well drilling well control equipment |
| CN111502546B (en) * | 2020-05-29 | 2021-11-12 | 中国石油天然气集团有限公司 | Method for turning off underground unit of rotary steering system through ground remote control |
| CN111980691A (en) * | 2020-09-03 | 2020-11-24 | 中国石油天然气集团有限公司 | Measurement system for determining formation pressure using downhole hydrocarbon detection |
| CN111980692A (en) * | 2020-09-03 | 2020-11-24 | 中国石油天然气集团有限公司 | Well killing method based on underground all-hydrocarbon content detection |
| CN112112626A (en) * | 2020-09-03 | 2020-12-22 | 中国石油天然气集团有限公司 | Bottom hole pressure control method based on underground hydrocarbon detection |
| CN111997597A (en) * | 2020-09-03 | 2020-11-27 | 中国石油天然气集团有限公司 | Method for controlling methane in stratum to invade shaft |
| CN111946335A (en) * | 2020-09-03 | 2020-11-17 | 中国石油天然气集团有限公司 | Method for obtaining formation pressure based on underground hydrocarbon detection technology |
| CN112112583A (en) * | 2020-10-30 | 2020-12-22 | 中国石油天然气集团有限公司 | Pressure control device for oil-gas well operation |
| US11859473B2 (en) * | 2020-11-10 | 2024-01-02 | Saudi Arabian Oil Company | Automatic in-situ gas lifting using inflow control valves |
| CN112145167B (en) * | 2020-11-10 | 2022-02-22 | 西南石油大学 | Fracturing dynamic bottom hole pressure calculation method based on construction data |
| CN112761600A (en) * | 2021-02-03 | 2021-05-07 | 沈阳航空航天大学 | Ground separate layer water injection well head intelligent control experiment system |
| CN113011756B (en) * | 2021-03-25 | 2022-06-10 | 中煤科工集团重庆研究院有限公司 | Coal mine gas extraction multi-source data acquisition and extraction effect judgment system and method |
| CN113250674B (en) * | 2021-04-27 | 2023-06-30 | 山东恒信电器集团有限公司 | Electric control system for petroleum drilling equipment |
| CN113503152A (en) * | 2021-06-08 | 2021-10-15 | 东台升华工具有限公司 | Drill bit working condition intelligent control system with pressure sensor |
| CN113589855B (en) * | 2021-07-09 | 2023-08-29 | 四川川庆石油钻采科技有限公司 | Material tank liquid level dynamic control method of particle drilling conveying system |
| CN113585974A (en) * | 2021-07-09 | 2021-11-02 | 四川川庆石油钻采科技有限公司 | Control method and system for high-pressure particle conveying |
| CN114198082A (en) * | 2021-11-26 | 2022-03-18 | 中国地质科学院勘探技术研究所 | Test device for simulating drilling of small-caliber drilling hole bottom under complex working conditions |
| CN114407214A (en) * | 2022-01-28 | 2022-04-29 | 广东高景太阳能科技有限公司 | Automatic regulating system for concentration of large-size silicon wafer cutting mortar liquid |
| CN115219321B (en) * | 2022-07-28 | 2023-04-18 | 西南石油大学 | Experimental device and method for testing wellbore pressure under jet leakage coexistence working condition |
Family Cites Families (8)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN2187224Y (en) * | 1993-03-18 | 1995-01-11 | 江汉石油管理局钻井工艺研究所 | Safety monitoring and automatic drill-feeding device for drilling |
| US5842149A (en) * | 1996-10-22 | 1998-11-24 | Baker Hughes Incorporated | Closed loop drilling system |
| US6035952A (en) * | 1996-05-03 | 2000-03-14 | Baker Hughes Incorporated | Closed loop fluid-handling system for use during drilling of wellbores |
| US6367566B1 (en) * | 1998-02-20 | 2002-04-09 | Gilman A. Hill | Down hole, hydrodynamic well control, blowout prevention |
| US20020112888A1 (en) | 2000-12-18 | 2002-08-22 | Christian Leuchtenberg | Drilling system and method |
| CA2344627C (en) | 2001-04-18 | 2007-08-07 | Northland Energy Corporation | Method of dynamically controlling bottom hole circulating pressure in a wellbore |
| CN1339650A (en) * | 2001-10-15 | 2002-03-13 | 刘刚 | Microcomputerized automatic control system for oil and gas well drilling throttling pressure |
| US7027968B2 (en) * | 2002-01-18 | 2006-04-11 | Conocophillips Company | Method for simulating subsea mudlift drilling and well control operations |
-
2003
- 2003-10-31 CN CNB2003101034331A patent/CN100353027C/en not_active Expired - Lifetime
-
2004
- 2004-10-28 CA CA2486235A patent/CA2486235C/en active Active
- 2004-10-29 US US10/976,544 patent/US7158886B2/en active Active
Cited By (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN104929620A (en) * | 2014-03-21 | 2015-09-23 | 韩文峰 | Drilling-fluid on-line extreme pressure lubricity tester |
| CN110886585A (en) * | 2019-12-02 | 2020-03-17 | 中国石油集团西部钻探工程有限公司 | Automatic throttle control device for back pressure compensation in drilling operation and use method thereof |
| CN113738339A (en) * | 2020-06-17 | 2021-12-03 | 中国石油天然气股份有限公司 | Control method and device for wellhead blowout making system in oilfield operation |
| CN113738339B (en) * | 2020-06-17 | 2024-01-30 | 中国石油天然气股份有限公司 | Control method and device for wellhead blowout system in oilfield operation |
Also Published As
| Publication number | Publication date |
|---|---|
| US20050096848A1 (en) | 2005-05-05 |
| US7158886B2 (en) | 2007-01-02 |
| CA2486235C (en) | 2012-09-25 |
| CN1611742A (en) | 2005-05-04 |
| CN100353027C (en) | 2007-12-05 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CA2486235A1 (en) | An automatic control system and method for bottom hole pressure in the underbalance drilling | |
| EP2999846B1 (en) | Influx detection at pumps stop events during well drilling | |
| CN202108504U (en) | Forecast system for flow difference, well kick and lost circulation | |
| NO330919B1 (en) | Well control method using continuous pressure painting during drilling | |
| CN100513736C (en) | Underground liquid level monitoring system and its method | |
| NO325151B1 (en) | Method and apparatus for dynamic prediction control when drilling using neural networks | |
| CN103032064A (en) | Method and device for detecting gas cut position in drilling process | |
| CN103615236A (en) | Method for real-time monitoring of formation pressure by means of remote mud logging information | |
| CA2841771C (en) | Well drilling methods with automated response to event detection | |
| US11756275B2 (en) | Auxiliary system and method for intelligent well control | |
| CN110513063B (en) | Pressure-controlled drilling system and control method thereof | |
| CN104727815A (en) | Real-time well drilling formation correction method and device | |
| CN116044332A (en) | Visual intelligent secondary well control method, system, device and storage medium | |
| CN114517675A (en) | Evaluation equipment and evaluation method for leakage and overflow monitoring instrument of three-high gas well | |
| CN210217665U (en) | Liquid level stability control system | |
| US10563505B2 (en) | Sample capture prioritization | |
| CN203335058U (en) | Coalbed-methane under-balanced horizontal well borehole cleaning monitoring device | |
| CN111980689A (en) | Method for controlling stratum crude oil invading shaft by using underground hydrocarbon detection technology | |
| WO2016210398A1 (en) | Fluid loss and gain for flow, managed pressure and underbalanced drilling | |
| CN217813444U (en) | Ultra-deep well underground condition detection and early warning system | |
| CN111927432A (en) | Method for controlling stratum carbon dioxide to invade shaft | |
| CN104863571A (en) | Pressure monitoring device based on coalbed gas double-barrel and double-circulation | |
| US20230127022A1 (en) | Intelligent Well Control System and Method for Surface Blow-Out Preventer Equipment Stack | |
| CN111997597A (en) | Method for controlling methane in stratum to invade shaft | |
| CN204609871U (en) | Prognoses system is revised on a kind of real-time drilling stratum |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| EEER | Examination request |