Testing the Performance Impact of Automation Applications on Different Drive Systems in Unconventional Well Development
- Tony Pink (NOV) | Andrew Coit (NOV) | Joseph Smith (NOV) | James Nieto (NOV)
- Document ID
- Society of Petroleum Engineers
- SPE/IADC Drilling Conference and Exhibition, 17-19 March, London, England, UK
- Publication Date
- Document Type
- Conference Paper
- SPE/IADC Drilling Conference and Exhibition
- 1.10.1 Drill string components and drilling tools (tubulars, jars, subs, stabilisers, reamers, etc), 1.6 Drilling Operations, 1.6.1 Drilling Operation Management, 1.5 Drill Bits, 1.10 Drilling Equipment, 1.6.6 Directional Drilling, 1.4.1 BHA Design, 1.10 Drilling Equipment, 7.2 Risk Management and Decision-Making, 7 Management and Information, 7.2.1 Risk, Uncertainty and Risk Assessment, 1.4 Drillstring Design, 1.13 Drilling Automation
- unconventional, automation, drive systems, optimization
- 0 in the last 30 days
- 257 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 8.50|
|SPE Non-Member Price:||USD 25.00|
Today, during the development of unconventionals, lack of knowledge about the downhole dynamics environment creates a culture of conservatism where excessive safety margins need to be applied to prevent damage to the rig equipment, drill bits, drill string and sensitive drilling tools. By using a combination of high-speed downhole data, surface applications, and an automated control system, this risk can be reduced, drilling performance improved and non-productive time reduced. Unconventional wells are typically drilled with several different types of drive systems, so on this project the impact of the automated drilling system was methodically tested in combination with the following BHA drive types:
Rotary steerable tools
Downhole motorized rotary steerable tools.Methods, Procedures, Process
This paper discusses the test program implemented across a 6-well project drilling in the Eagle Ford unconventional shale formation in South Texas. It was essential at the pre-planning phase that key performance indicators were identified and a solid test plan was designed. A road map was put in place to fully analyze the performance benefits where the automated drilling applications were tested against drive system, formation type and wellbore geometry. The primary objectives were to identify which applications combined with which drive system delivered the largest, consistent performance gains and the greatest cost savings. The paper includes a detailed description of the various automated applications tested:
A surface-located, active stick-slip mitigation device
A closed-loop high-speed downhole weight on bit controller
An automated closed-loop, high-speed downhole data driven autodriller, aimed at maximizing rate of penetration whist minimizing all modes of vibration.Results, Observations, Conclusions
These technologies bring significant benefits to our industry, especially in the development of unconventional assets where it is becoming increasingly difficult to deliver step changes in performance with current crews and technology. The high-speed downhole-driven control of the rig equipment allowed the driller and the customer representatives to maximize the performance of the rig without compromising safety or the reliability of the equipment. Drilling with automated motor BHAs and automated non-motorized rotary steerable BHAs allowed for repeated improvements in drilling performance of 37%, well on well. The fact that this performance increase is repeatable offers significant bottom line value for operators, by allowing reliable well delivery, forecasting and overall reduced well cost.Novel/Additive Information
Downhole-automated drilling control described within this case study is a powerful tool to be used by existing drillers and directional drillers. The drilling crew must use the automated control system in partnership with specialized automated drilling applications to realize higher performance, without sacrificing safety margins or tool life. Even with an automated drilling system, optimum performance is measurably more difficult to achieve without optimal BHA design and drive type.
|File Size||8 MB||Number of Pages||24|
Attar, F., Grauwmans, R., & Ikhajiagbe, O. (2014, January 19). Soft Torque Impact on Drilling Performance in Qatar. International Petroleum Technology Conference. doi: 10.2523/17651-MS.
Dunlop, J., Isangulov, R., Aldred, W. D., et al. 2011. Increased Auto of Penetration Through Automation. Paper SPE 139897 presented at the SPE/IADC Drilling Conference and Exhibition, Amsterdam, The Netherlands, 1-3 March. http://dx.doi.org/10.2118/139897-MS.
Ertas, D., Bailey, J. R., Wang, L., et al. 2013. Drillstring Mechanics Model for Surveillance, Root Cause Analysis, and Mitigation of Torsional and Axial Vibrations. Paper SPE 163420 presented at the SPE/IADC Drilling Conference and Exhibition, Amsterdam, The Netherlands, 5-7 March. http://dx.doi.org/10.2118/163420-MS.
Kyllingstad, A., and Nessjøen, P. J. 2009. A New Stick-Slip Prevention System. Paper SPE 119660 presented at the SPE/IADC Drilling Conference and Exhibition, Amsterdam, The Netherlands, 17-19 March. http://dx.doi.org:10.2118/119660-MS.
Kyllingstad, A., and Nessjøen, P. J. 2010. Hardware-in-the-Loop Simulations Used as a Cost-Efficient Tool for Developing an Advanced Stick-Slip Prevention System. Paper SPE 128223 presented at the SPE/IADC Drilling Conference and Exhibition, New Orleans, Louisiana, USA, 2-4 February. http://dx.doi.org/10.2118/128223-MS.
Lines, L. A., Stroud, D. R. H., and Conveney, V. A. 2013. Torsional Resonance – An Understanding Based on Field and Laboratory Tests with Latest Generation Point-the-Bit Rotary Steerable System. Paper SPE 163428 presented at the SPE/IADC Drilling Conference and Exhibition, Amsterdam, The Netherlands, 5-7 March. http://dx.doi.org/10.2118/163428-MS.
Nessjøen, P. J., Kyllingstad, A., Dambrosio, P., et al. 2011. Field Experience with an Active Stick-Slip Prevention System. Paper SPE 139956 presented at the SPE/IADC Drilling Conference and Exhibition, Amsterdam, The Netherlands, 1-3 March. http://dx.doi.org/10.2118/139956-MS.
Reckmann, H., Pushkar, J., Kpetehoto, F., Chandrasekaran, S., and Macpherson, J. 2010. MWD Failure Rates Due to Drilling Dynamics. Paper IADC/SPE 127413 presented at the IADC/SPE Drilling Conference amd Exhibition held in New Orleans, Louisiana, USA, 2-4 February. http://dx.doi.org/10.2118/127413-MS.
Smith, W. F. and Hashemi, J. 2006. Foundations of Materials Science and Engineering, fourth edition. New York, New York. McGraw-Hill. United States Energy Information Administration (EIA). 2010. Eagle Ford Shale Play, Western Gulf Basin, South Texas Map. http://www.eia.gov/oil_gas/rpd/shaleusa9.pdf (accessed 1 June 2014).
Pink, T.P., Harell, L., Perez, D., Carrico, C., Mackinnon, P., 2010 Paper, Integrated drilling optimization and downhole drilling dynamics enables PDC bits to drill in the Colorado region of the San Juan unconventional gas basin. Presented at SPE/IADC Drilling Conference and Exhibition held in Amsterdam, The Netherlands, 1–3 March 2011.
Pink, T.P., Koederitz, W., Barrie, A., Bert, D., Overgaard, D., 2013, SPE Paper 166428 Closed Loop Automation of Downhole Weight on Bit Improves Sliding Performance and Reduces Conservatism in Unconventional Horizontal Well Development, Presented at at the SPE Annual Technical Conference and Exhibition held in New Orleans, Louisiana, USA, 30 September–2 October 2013.
Pink, T.P., Bruce, A., Kverneland, H., Applewhite, B., 2011, SPE/IADC 150973 Building an automated drilling system where surface machines are controlled by down-hole and surface data to optimize the well construction process. Presented at the 2012, SPE/IADC Drilling Conference, San Diego, California.