Reducing differential sticking during sampling
원문보기
IPC분류정보
국가/구분
United States(US) Patent
등록
국제특허분류(IPC7판)
E21B-049/08
E21B-049/10
출원번호
US-0071513
(2013-11-04)
등록번호
US-9109431
(2015-08-18)
발명자
/ 주소
Villareal, Steven
Pop, Julian J.
출원인 / 주소
Schlumberger Technology Corporation
대리인 / 주소
Hewitt, Cathy
인용정보
피인용 횟수 :
0인용 특허 :
20
초록▼
A method includes lowering a downhole tool via a pipe into a wellbore drilled through a formation via the pipe and establishing a fluid communication between the downhole tool and the formation at a location in the wellbore. The method also includes extracting from the formation a first fluid stream
A method includes lowering a downhole tool via a pipe into a wellbore drilled through a formation via the pipe and establishing a fluid communication between the downhole tool and the formation at a location in the wellbore. The method also includes extracting from the formation a first fluid stream through the fluid communication and passing the first fluid stream through the downhole tool for a first duration. The method further includes breaking the fluid communication between the downhole tool and the formation, moving the pipe in the wellbore, and reestablishing the fluid communication between the downhole tool and the formation essentially at the location in the wellbore subsequent to moving the pipe in the wellbore.
대표청구항▼
1. A method, comprising: lowering a downhole tool via a pipe into a wellbore drilled through a formation via the pipe;performing a sticking test;estimating a maximum duration on station based on results of the sticking test and a sticking model;establishing a fluid communication between the downhole
1. A method, comprising: lowering a downhole tool via a pipe into a wellbore drilled through a formation via the pipe;performing a sticking test;estimating a maximum duration on station based on results of the sticking test and a sticking model;establishing a fluid communication between the downhole tool and the formation at a location in the wellbore;extracting from the formation a first fluid stream through the fluid communication and passing the first fluid stream through the downhole tool for a first duration, wherein the first duration has a predetermined length based on the estimated maximum duration on station;breaking the fluid communication between the downhole tool and the formation;moving the pipe in the wellbore, wherein moving the pipe in the wellbore comprises: moving the downhole tool away from the location after breaking the fluid communication between the downhole tool and the formation; and thenmoving the downhole tool towards the location before reestablishing the fluid communication between the downhole tool and the formation essentially at the location;reestablishing the fluid communication between the downhole tool and the formation essentially at the location in the wellbore subsequent to moving the pipe in the wellbore;extracting, from the formation, a second fluid stream through the fluid communication and passing the second fluid stream through the downhole tool for a second duration, wherein the second duration has a predetermined length based on the estimated maximum duration on station; andcapturing, in the downhole tool, a fluid sample of the second fluid stream. 2. The method of claim 1 further comprising: measuring the composition of one of the first and second fluid streams passing through the tool;comparing the measured composition with a model or expected composition; andinitiating the fluid sample capture based on the comparison. 3. The method of claim 1 further comprising: measuring a parameter indicative of a fraction of mud filtrate or formation connate fluid in the first or second fluid streams;comparing the indicated fraction with a prediction based on a model; andinitiating the fluid sample capture based on the comparison. 4. The method of claim 1 wherein a drill bit is connected at a distal end of the pipe, and wherein the method further comprises drilling the formation using the drill bit. 5. The method of claim 1 wherein one of the first and second durations is predetermined based on a prediction of a model simulating sampling operations. 6. The method of claim 1 wherein one of the first and second durations is predetermined based on the well or operating conditions. 7. The method of claim 1 wherein one of the first and second durations is predetermined based on the sticking model in combination with the sticking test performed in situ. 8. The method of claim 1 wherein establishing a fluid communication comprises extending a probe of the downhole tool to engage a wall of the wellbore. 9. The method of claim 1 comprising measuring a property indicative of a composition of the extracted fluid of each of the first and second fluid streams. 10. The method of claim 1 comprising measuring a property indicative of a density or viscosity of the extracted fluid of the second fluid stream; and measuring a pressure and temperature of the extracted fluid of the second fluid stream. 11. The method of claim 1, comprising: sliding the pipe to the location in the wellbore;releasing tension in the pipe; andmarking the pipe while the pipe is at the location to provide a reference point for repositioning the pipe. 12. The method of claim 11, wherein reestablishing the fluid communication comprises using the marking to position the pipe essentially at the location. 13. The method of claim 1, comprising: sliding the pipe to the location in the wellbore; andcorrelating a bit depth to a formation evaluation measurement log. 14. The method of claim 13, wherein reestablishing the fluid communication comprises using the bit depth to position the pipe essentially at the location. 15. A method, comprising: conveying a downhole tool to a location in a wellbore that extends into a formation, wherein the downhole tool is part of a bottomhole assembly (BHA) that is disposed between a drill bit and a pipe;performing a sticking test;estimating a maximum duration on station based on results of the sticking test and a sticking model;holding the downhole tool at the location during a first predetermined time period while operating the downhole tool to monitor a parameter associated with the formation, wherein at least one of the pipe, the drill bit, and the downhole tool substantially continuously abuts a sidewall of the wellbore during the first predetermined time period, and the first predetermined time period is based on the estimated maximum duration on station;moving the pipe in a first direction in the wellbore to move the downhole tool away from the location after the predetermined time period;moving the pipe in a second direction in the wellbore to move the downhole tool essentially back to the location; andholding the downhole tool essentially at the location during a second predetermined time period while operating the downhole tool to monitor the parameter associated with the formation, wherein at least one of the pipe, the drill bit, and the downhole tool substantially continuously abuts the sidewall of the wellbore during the second predetermined time period, and the second predetermined time is based on the estimated maximum duration on station. 16. The method of claim 15 further comprising: performing the sticking test before conveying the downhole tool to the location, wherein performing the sticking test comprises holding the downhole tool at another location for a third predetermined time period;releasing torque and tension in the pipe before holding the downhole tool at the location during the first predetermined time period;maintaining engagement of the sidewall of the wellbore with a probe extended from the downhole tool during the first and second predetermined time periods;creating a mark on the pipe while the pipe is at the location during the first predetermined time period, after releasing the torque and tension in the pipe, and using the mark to move the downhole tool essentially back to the location;correlating a bit depth to a formation evaluation measurement log and using the correlated bit depth to move the downhole tool essentially back to the location; andlengthening the wellbore using the drill bit after holding the downhole tool essentially at the location during the second predetermined time period. 17. The method of claim 16 wherein: the first predetermined time ranges between about 20 minutes and about 2 hours;the second predetermined time ranges between about 20 minutes and about 2 hours; andthe third predetermined time is about 10 minutes. 18. A method, comprising: during a first time period, lowering a bottom-hole-assembly (BHA) having a logging-while-drilling (LWD) tool into a wellbore, wherein the wellbore extends into a subterranean formation, and wherein the BHA is disposed between a pipe and a drill bit;during a second time period after the first time period, lengthening the wellbore via drilling with the drill bit while circulating drilling fluid in the wellbore and the pipe, and then halting the drilling and releasing torque along the pipe;during a third time period after the second time period, performing a sticking test by keeping the BHA stationary while maintaining the circulation of the drilling fluid circulation, then measuring a hook load associated with the pipe, the BHA, and the drill bit, and then estimating a maximum duration on station based on the measured hook load;during a fourth time period after the third time period, sliding the LWD tool down the wellbore from a first location above a sampling location to a second location below the sampling location while generating a first formation evaluation (FE) measurement log and correlating a depth of the drill bit within the wellbore with the first FE measurement log;during a fifth time period after the fourth time period, sliding the LWD tool up the wellbore to essentially the sampling location while generating a second FE measurement log and correlating the drill bit depth with the second FE measurement log;during a sixth time period after the fifth time period, releasing tension in the pipe and then making a mark on the pipe at a wellsite from whence the wellbore extends;during a seventh time period after the sixth time period, engaging the LWD tool with a wall of the wellbore;during an eighth time period after the seventh time period, drawing fluid from the subterranean formation into the downhole tool and monitoring at least one property indicative of at least one of a composition, a contamination, and a thermo-physical property of the drawn fluid, wherein the seventh time period has a predetermined length that is based on the estimated maximum duration on station;during a ninth time period after the eighth time period, disengaging the LWD tool from the wall of the wellbore and moving the LWD tool along a longitudinal axis of the wellbore in a first direction away from the sampling location;during a tenth time period after the ninth time period, moving the LWD tool along the longitudinal axis of the wellbore in a second direction essentially to the sampling location utilizing at least one of the mark on the pipe, the first FE measurement log, and the second FE measurement log;during an eleventh time period after the tenth time period, engaging the LWD tool with the wall of the wellbore at essentially the sampling location; andduring a twelfth time period after the eleventh time period, drawing fluid from the subterranean formation into the downhole tool and monitoring the at least one property of the drawn fluid, wherein the eleventh time period has a predetermined length that is based on the estimated maximum duration on station. 19. The method of claim 18 further comprising: during a thirteenth time period after the twelfth time period, directing a sample of the drawn fluid into a sample chamber of the LWD tool.
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이 특허에 인용된 특허 (20)
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Michaels John M. (Houston TX) Leder John T. (Bellaire TX) Cernosek James T. (Missouri City TX), Method and apparatus for acquiring and processing subsurface samples of connate fluid.
Berard Michel V. (Palaiseau FRX) Eisenmann Pierre (Paris FRX) Jinzaki Yoshinobu (Tokyo JPX) Dubourg Isabelle M. (Malakoff FRX), Method and apparatus for correcting a pressure measurement for the influence of temperature.
Vannuffelen,Stephane; Kamiya,Akira; Miyashita,Masaki; Indo,Kentaro; Ciglenec,Reinhart; Yamate,Tsutomu, Method and apparatus for downhole spectral analysis of fluids.
Wraight Peter (Missouri City TX) Mayes James C. (Sugar Land TX) Orban Jacques (Sugar Land TX), Video system and method for determining and monitoring the depth of a bottomhole assembly within a wellbore.
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