Search citation statements
Paper Sections
Citation Types
Year Published
Publication Types
Relationship
Authors
Journals
This paper describes the strategies and practices used to deliver best in class ROP performance in three different applications (through salt, soft clastic and medium-hard clastic formations) on the Deepwater Gulf of Mexico. A novel advanced bit design was tested with mechanical (WOB and RPM) and hydraulic (flow rate) parameters beyond the current operational envelope. Several operational and equipment limits were also tested and moved beyond the previous levels. The drilling parameters and results from the three applications are also included. Over the last couple of years, the drilling cost for deep-water drilling has been reduced through continuous performance improvement resulting in a "Beyond the Best" mentality. Every time a new best in class ROP performance is achieved, questions about "What else can be done", are asked. A project was taken up to challenge the current drilling operational envelope resulting in ROPs faster than ever in the Deepwater Gulf of Mexico. Integrated well planning combining operator and service provider knowhow and modeling capability were used to identify current operational limits and the required changes to go beyond them. BHA configuration and downhole tools were design and adjusted accordingly. Rig equipment were also reviewed and modified. The novel advanced bit design, with 3D cutting elements combining the shearing action of conventional PDC cutters with the crushing action of tungsten carbide insert, was selected by the project due to its capability of delivering less torque when higher mechanical parameters (WOB and RPM) are used. Field data demonstrates that using WOB up to 70,000 lbs while drilling with a 14-3/4" bit through medium-hard rock resulted in 9 % increase in ROP (103.2 ft/hr), when compared with the previous fastest ROP achieved while drilling similar formations in the field. Also, using 220 rpm while drilling trough salt with a 16-1/2" bit delivered 12% increase in ROP (307.3 ft/hr), when compared with the previous best performance. Furthermore, using 220 rpm in combination with 1460 gpm flow rate (22% above the normal flow rate), while drilling with a similar 16-1/2" bit through interbedded soft rock formations delivered 91% increase in ROP (368.7 ft/hr), when compared with the previous fastest ROP achieved while drilling similar formations in the field. The cuttings load limit in the annulus was tested beyond its current limit (3%) without observing hole pack off or stuck pipe issues. No vibration was observed while operating at the surface torque limit. A cost saving of over $2M was realized from this performance improvement effort. The identified opportunities for improvement and lessons learned included in the paper have led to best practices for future wells resulting in a valuable benchmark benefiting practicing engineer involved in similar projects. Furthermore, operational parameters used in the project confirm the robustness and benefits of the novel advanced bit design used in the project delivering higher ROP with a smooth torque response.
This paper describes the strategies and practices used to deliver best in class ROP performance in three different applications (through salt, soft clastic and medium-hard clastic formations) on the Deepwater Gulf of Mexico. A novel advanced bit design was tested with mechanical (WOB and RPM) and hydraulic (flow rate) parameters beyond the current operational envelope. Several operational and equipment limits were also tested and moved beyond the previous levels. The drilling parameters and results from the three applications are also included. Over the last couple of years, the drilling cost for deep-water drilling has been reduced through continuous performance improvement resulting in a "Beyond the Best" mentality. Every time a new best in class ROP performance is achieved, questions about "What else can be done", are asked. A project was taken up to challenge the current drilling operational envelope resulting in ROPs faster than ever in the Deepwater Gulf of Mexico. Integrated well planning combining operator and service provider knowhow and modeling capability were used to identify current operational limits and the required changes to go beyond them. BHA configuration and downhole tools were design and adjusted accordingly. Rig equipment were also reviewed and modified. The novel advanced bit design, with 3D cutting elements combining the shearing action of conventional PDC cutters with the crushing action of tungsten carbide insert, was selected by the project due to its capability of delivering less torque when higher mechanical parameters (WOB and RPM) are used. Field data demonstrates that using WOB up to 70,000 lbs while drilling with a 14-3/4" bit through medium-hard rock resulted in 9 % increase in ROP (103.2 ft/hr), when compared with the previous fastest ROP achieved while drilling similar formations in the field. Also, using 220 rpm while drilling trough salt with a 16-1/2" bit delivered 12% increase in ROP (307.3 ft/hr), when compared with the previous best performance. Furthermore, using 220 rpm in combination with 1460 gpm flow rate (22% above the normal flow rate), while drilling with a similar 16-1/2" bit through interbedded soft rock formations delivered 91% increase in ROP (368.7 ft/hr), when compared with the previous fastest ROP achieved while drilling similar formations in the field. The cuttings load limit in the annulus was tested beyond its current limit (3%) without observing hole pack off or stuck pipe issues. No vibration was observed while operating at the surface torque limit. A cost saving of over $2M was realized from this performance improvement effort. The identified opportunities for improvement and lessons learned included in the paper have led to best practices for future wells resulting in a valuable benchmark benefiting practicing engineer involved in similar projects. Furthermore, operational parameters used in the project confirm the robustness and benefits of the novel advanced bit design used in the project delivering higher ROP with a smooth torque response.
The high cost of deepwater operations places constant focus on the time spent on hole-making and non-hole-making activities. Substantial work has been done to minimize non-productive time, and recently the time spent making hole has received renewed focus. This paper provides an example workflow for the latter for two large hole sections in a recent deepwater well in the Gulf of Mexico (GOM). The relationships between mechanical and hydraulic power input and rate of penetration (ROP) are well known, and recent publications have provided examples of very high ROP in large hole sizes drilled through sediments and salt in GOM. Optimization efforts have driven improvements in bits, directional drilling systems and drillstring components to the point that the performance limiter is the rig equipment; for example, solids handling equipment and top drive power. Top drives on some deepwater rigs deliver 2,600 horsepower (HP), or 55 klbf-ft of torque at 250 RPM. Fully exploiting this has yielded ROP over 350 ft/hr in 16½-in. salt sections. The rig that drilled the well in this study utilized a smaller top drive capable of delivering approximately 1,150 HP. The challenge was to optimize bit, drilling system, drillstring design and operating parameters to deliver the highest possible ROP given the available horsepower. The goal was to make cuttings handling the active limiter. A key consideration for bit design was efficiency; that is, the ability to convert power into volume of rock removed. Equally important were lateral and torsional stability, which affect power wasted while drilling oversized, rugose hole and peak torque for a given mean torque, and thus the window of available operating parameters. These considerations led to selection of advanced hybrid PDC-TCI bits. The desire for minimal torque and drag and precise directional control through sediments and salt led to the selection of rotary steerable technology with continuous proportional steering. A simple model linking drilling parameters and rate of penetration was developed based on offset data and used to establish expected weights on bit and rotary speeds for optimal bit performance. Stabilization of the bottom hole assembly was optimized considering operating parameters and application requirements. The drillstring design maximized torsional stiffness and capacity so the torque and rotary speed could be adjusted as the well transitioned from vertical to directional. The detailed planning and system specification yielded excellent performance. The 26-in. and 16½-in. hole sections were drilled in single runs, on target and with minimal vibration. ROP in the 26-in. interval was 15% faster than the previous best despite drilling a section nearly twice as long. ROP in the 16½-in. section was 38% faster than the rig's previous best. Reductions in drilling time contributed $1M in savings.
scite is a Brooklyn-based organization that helps researchers better discover and understand research articles through Smart Citations–citations that display the context of the citation and describe whether the article provides supporting or contrasting evidence. scite is used by students and researchers from around the world and is funded in part by the National Science Foundation and the National Institute on Drug Abuse of the National Institutes of Health.
hi@scite.ai
10624 S. Eastern Ave., Ste. A-614
Henderson, NV 89052, USA
Copyright © 2024 scite LLC. All rights reserved.
Made with 💙 for researchers
Part of the Research Solutions Family.