Reaming on Demand - Selective Activation of an Integrated Under Reamer at the Grane Field in the North Sea

Pragt, Jos; Herberg, Wolfgang; Meister, Matthias; Clemmensen, Carl Christian; Grindhaug, Gaute; Hanken, K. J.

doi:10.2118/146501-ms

Cited by 15 publications

(3 citation statements)

References 6 publications

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“…To overcome the limitations associated with the use of traditional ball drop reamers, the development of a fully integrated, expandable under reamer, with unlimited activation and deactivation cycles via downlinking, was initiated in 2007 by a major Norwegian operator in collaboration with a service company [1,2].…”

Section: Integrated Under Reamermentioning

confidence: 99%

“…In that test the reamer drilled and reamed hard formation, while the unlimited activation/deactivation was tested out along with all failsafe systems. The initial testing was followed by an extended field test phase in Norway, on the Grane field, where seven runs were successfully completed with 5865 m drilled and 1722 m reamed [1]. The tool fleet was expanded, and several sizes are now available for commercial use ( Table 2).…”

Section: Integrated Under Reamermentioning

confidence: 99%

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New On-Command Integrated Under Reamer Elevated Drilling Performance, Reduced Operational Risks and Lowered Cost: A Case Study in the Oseberg South Field

Ahlberg

Fang

Hoff

et al. 2016

Day 1 Wed, April 20, 2016

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This paper presents technical features and associated benefits of a recently developed under reamer technology and its applications in the offshore Norway Oseberg South field to drill 12 ¼Љ ϫ 13 ½Љ and 8 ½Љ ϫ 9 ½Љ sections. It discusses the results of the operations and demonstrates how the operations benefited from the new technology.In today's drilling operations, expandable reamers are broadly used to support optimized casing and completion programs and to reduce operational risks such as high Equivalent Circulating Density (ECD), drilling troublesome formations and reaming well path conformities. The currently available hole enlargement technologies, such as ball drop and hydraulically activated reamers, carry intrinsic risks and limitations.To address the challenges associated with currently available under reamer technologies, expandable reamer technology was recently developed jointly by a service company and a major operator, and was field tested offshore Norway. The under reamer, which is fully integrated with the company's existing Rotary Steerable System (RSS) Bottom Hole Assembly (BHA), provides unlimited, on-command activation cycles, optimal placement within the BHA in multiple configurations and real-time feedback via mud-pulse telemetry. The feedback from the reamer includes confirmation of blade activation status, health of the tool, and vibration and stick-slip measurements. Because of the flexibility of its placement in the BHA, the reamer can reduce the length of the rat hole to a minimum of 4 m compared to the standard 30 to 70 m in the same drilling run, eliminating the need for a dedicated clean-out run. The reamer also enables reliable and unlimited activation / deactivation cycles with each cycle taking less than 5 minutes, saving operational costs for the operators.The under reamer was successfully deployed to drill challenging 12 ¼Љ ϫ 13 ½Љ and 8 ½Љ ϫ 9 ½Љ sections in the offshore Norway Oseberg South field. The 2497 m long 12 ¼Љ ϫ 13 ½Љ section and 900 m long 8 ½Љ ϫ 9 ½Љ section were both drilled to Total Depth (TD) in one run, with all requirements on directional control and Measurement While Drilling (MWD) / Logging While Drilling (LWD) met. The technology was proven to be a reliable and flexible hole enlargement while drilling solution that elevates drilling performance, reduces operational risks and lowers operational costs.

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Section: Integrated Under Reamermentioning

confidence: 99%

Section: Integrated Under Reamermentioning

confidence: 99%

New On-Command Integrated Under Reamer Elevated Drilling Performance, Reduced Operational Risks and Lowered Cost: A Case Study in the Oseberg South Field

Ahlberg

Fang

Hoff

et al. 2016

Day 1 Wed, April 20, 2016

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“…The Grane oil field is situated in the North Sea, about km west of the city of Haugesund, Norway with a water depth of 127m ( Figure 1) and contains heavy crude oil found in turbidite sandstone from the Tertiary period (Pragt et al, 2012). It was first discovered by Norsk Hydro in 1991 and is currently operated by Equinor ASA.…”

Section: Introductionmentioning

confidence: 99%

1‐D, 2‐D, and 3‐D Monte Carlo Ambient Noise Tomography Using a Dense Passive Seismic Array Installed on the North Sea Seabed

et al. 2020

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In a variety of geoscientific applications we require 3‐D maps of properties of the Earth's interior and the corresponding map of uncertainties to assess their reliability. On the seabed it is common to use Scholte wave dispersion data to infer these maps using inversion‐based imaging theory. Previously we introduced a 3‐D fully nonlinear Monte Carlo tomography method that inverts for shear velocities directly from frequency‐dependent travel time measurements and which improves accuracy of the results and better estimates uncertainties. Here for the first time we apply that method to real data and compare it to two previous methods. We cross correlated 6.5 hr of ambient noise data recorded on a dense seismic array over Grane, North Sea, and observed two Scholte wave modes. For each mode, phase velocity maps are estimated using Eikonal tomography, which are in turn used to study the shear‐wave velocity structure of the subsurface. We applied three nonlinear inversion methods to the Grane data: standard 1‐D depth inversions, a 2‐D joint inversion along a vertical cross section, and a fully 3‐D inversion. We compare the shear‐velocity and uncertainty structures estimated along the same 2‐D cross section. Thus we show that the standard 1‐D inversion method creates significant errors in the results due to the independence of those 1‐D inversions, whereas the 2‐D and 3‐D inversions improve results by accounting for lateral spatial correlations. The 3‐D inversion bypasses the initial seabed Eikonal tomography step, thus avoiding the errors that the initial step introduces into subsequent 1‐D and 2‐D inversions.

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Underreamer with Real-time Communications and Optimal Bit Design Achieves Successful Lateral Well Placement - A Case Study

Chiniwala

Radford

Bacon³

et al. 2014

SPE Annual Technical Conference and Exhibition

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As long as underreamers have existed in the oil field, operators have wanted a clearer understanding of how these tools are operating in real time. A new integrated underreamer that provides real-time communication via the same mud pulse telemetry system as the familiar MWD/LWD/RSS (Measurement While Drilling/Logging While Drilling/Rotary Steerable System) tools and allows the placement of the underreamer closer to the bit (to aid vibration management and minimize rat hole length), has been used. This advanced underreamer system reveals the current condition of the tool and the position of the blades (implied hole caliper) to the operator, additionally, it uses internal hydraulic oil pumped-pressure activation (and deactivation) of the blades. This integrated underreamer was used to simultaneously drill and underream an 8½-in. × 9⅞-in. pilot hole section interval and then side-track to drill an 8½-in. × 9⅞-in. mainbore lateral section to the top reservoir horizon. A case study in the UK North Sea Harding field is included as part of this paper describing the critical challenges of simultaneously drilling and underreaming a development well, including the equivalent circulating density (ECD) management within narrow pressure margins. Underreaming an 8½-in. × 9⅞-in. wellbore all the way to TD was viewed as the most acceptable method to manage ECD and be able to get the production liner to bottom. Other ECD control methods used on this well, and detailed in this paper, include a combination of adjustments of rate of penetration (ROP) and rotations per minute (RPM), drilling fluid rheology management and pumping of sweeps at different stages of drilling to aid hole cleaning. The PDC (polycrystalline diamond compact) bit design was matched to that of the reamer with a proprietary technology to optimize the drilling assembly and minimize stick-slip or coupled lateral vibrations. The reaming system was used to drill and underream 6,645 ft. in two runs totalling 288 hours on-bottom drilling, with minimal vibrations. The well was drilled with an inclined trajectory of up to 90° with as much as 5°/100 ft. dog leg severity. The reamer appeared to provide an in-gauge borehole allowing for successful running, rotation and cementing of approximately 4,300 ft. of 7-5/8″ liner without any issues, demonstrating superior borehole quality. This paper outlines the problems anticipated in this challenging well, the thinking behind the unusual reamer selection, the method for proper synchronization with the pilot bit, and the keys to overall success.

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Reaming on Demand - Selective Activation of an Integrated Under Reamer at the Grane Field in the North Sea

Cited by 15 publications

References 6 publications

New On-Command Integrated Under Reamer Elevated Drilling Performance, Reduced Operational Risks and Lowered Cost: A Case Study in the Oseberg South Field

New On-Command Integrated Under Reamer Elevated Drilling Performance, Reduced Operational Risks and Lowered Cost: A Case Study in the Oseberg South Field

1‐D, 2‐D, and 3‐D Monte Carlo Ambient Noise Tomography Using a Dense Passive Seismic Array Installed on the North Sea Seabed

Underreamer with Real-time Communications and Optimal Bit Design Achieves Successful Lateral Well Placement - A Case Study

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