Continuous Motion Rig. A Detailed Study of a 750 Ton Capacity, 3600 m/hr Trip Speed Rig

Grinrod, M.; Krohn, Helge

doi:10.2118/139403-ms

Cited by 2 publications

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“…Studies have shown that drilling automation can decrease the time required to attain a targeted depth by around 30%-40%, by eliminating the interruptions that occur with traditional drilling methods [6][7][8]. By avoiding interruptions to the drilling process, the wellbore will be less likely to collapse and will avoid problems such as "stuck pipe" [9].…”

Section: Drilling Automationmentioning

confidence: 99%

“…Significant improvement in time to run casing. Tripping speeds of 1800 to 3600 m/hr have been demonstrated in field trials, as have casing running speeds of 900 m per hour [8]. Both of these values exceed the "perfect well" speeds used as a theoretical maximum in the study by Brett [13,14], where the maximum theoretical tripping speed was estimated at 1645 m per hour and casing runs were estimated at 820 m per hour.…”

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confidence: 94%

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Impact of Drilling Costs on the US Gas Industry: Prospects for Automation

et al. 2018

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Recent low gas prices have greatly increased pressure on drilling companies to reduce costs and increase efficiency. Field trials have shown that implementing automation can dramatically reduce drilling costs by reducing the time required to drill wells. This study uses the DYNamic upstreAm gAs MOdel (DYNAAMO), a new techno-economic, bottom-up model of natural gas supply, to quantitatively assess the economic impact of lower drilling costs on the US upstream gas industry. A sensitivity analysis of three key economic indicators is presented, with results quoted for the most common field types currently producing, including unconventional and offshore gas. While all operating environments show increased profitability from drilling automation, it is found that conventional onshore reserves can benefit to the greatest extent. For large gas fields, a 50% reduction in drilling costs is found to reduce initial project breakevens by up to 17 million USD per billion cubic metres (MUSD/BCM) and mid-plateau breakevens by up to 8 MUSD/BCM. In this same scenario, additional volumes of around 160 BCM of unconventional gas are shown to become commercial due to both the lower costs of additional production wells in mature fields and the viability of developing new resources held in smaller fields. The capital efficiency of onshore projects increases by 50%–100%, with initial project net present value (NPV) gains of up to 32%.

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Section: Drilling Automationmentioning

confidence: 99%

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confidence: 94%

Impact of Drilling Costs on the US Gas Industry: Prospects for Automation

et al. 2018

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Mitigating Surge and Swab by Changing Tripping from a Batch to a Continuous Process

Pilgrim

Butt

2022

Day 2 Thu, March 17, 2022

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A significant portion of the time required to drill an oilwell is spent moving the drillpipe in or out of the wellbore, called "Tripping". The drill crew must trip pipe for numerous reasons. These include changing the bit as it wears out, inserting new casing strings, cleaning and treating the drillpipe and/or wellbore to allow more efficient drilling, and to run in various tools that perform specific jobs required at certain times in the oilwell construction plan. The traditional tripping process (TTP) inherently creates pressure transients developed from stopping and starting the vertical motion of the drillpipe during connections. These pressure transients called, "Swapping" and "Surging", contribute to borehole instability, restrict tripping speed, and increase non-productive time (NPT). This paper focuses on the benefits that can be gained from a bottom hole pressure (BHP) surge/swab perspective. Specifically, how these undesirable pressure transients can be dramatically reduced by modifying the TTP from a start/stop (batch) process to a continuous tripping process (CTP), where drillpipe tripping speed is kept constant throughout the entire tripping sequence and thereby significantly reducing the numerous starts and stops associated with traditional tripping. In this paper both the TTP and CTP systems were kinematically modeled using a custom simulator coded in C#. It is important to note that all the equipment used in the modified CTP exists and has only been reconfigured to facilitate a continuous process. This is inclusive of real-life limits for such items as derrick height, traveling block (TB) height as well as velocity, acceleration and inertia limits for TB, crown blocks, drawworks, their associated reeving configurations as well as racking system arms, grippers, and latches. The simulation results indicates that for a continuous tripping system we can achieve a ~73% slower average pipe speed that has an overall tripping speed approximately 4 times faster than traditional tripping. CTP decreased BHP deviation significantly. The continuous tripping process was awarded a patent by USTPO in 2016, US 9,441.247 B2.

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Continuous Motion Rig. A Detailed Study of a 750 Ton Capacity, 3600 m/hr Trip Speed Rig

Cited by 2 publications

References 0 publications

Impact of Drilling Costs on the US Gas Industry: Prospects for Automation

Impact of Drilling Costs on the US Gas Industry: Prospects for Automation

Mitigating Surge and Swab by Changing Tripping from a Batch to a Continuous Process

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