North Sea Advances in Extended Reach Drilling

Eck-Olsen, Johan; Sletten, Haakon; J.T., Reynolds; Samuell, J.G.

doi:10.2523/25750-ms

Cited by 5 publications

(1 citation statement)

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“…Extended Reach Drilling (ERD) is a technique to drill directional/horizontal wells beyond the routine capabilities of drilling rigs and tools. ERD was initiated in 1980's and rapidly evolved during the 1990's [1][2][3][4]. Naegel et al [5] reported an ERD well with a 20,341.2 ft horizontal departure at 5,577 ft true vertical depth (TVD).…”

Section: Introductionmentioning

confidence: 99%

An Analytical Model for Axial Force Transfer and the Maximum Compression Point of Work Strings in Extend Reach Drilling

Shaibu

2020

IMST

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Complex work string dynamics are often observed when one is investigating the limit of Extended Reach Drilling (ERD), yet the underlying physical causes of anomalous problems are often not fully understood and is thus a topic of ongoing research interest. Theoretical models capturing tubular dynamics have been previously proposed to analyze force transfer in work strings, yet there is significant confusion regarding these models because their published versions are not entirely consistent and, in many cases, do not meet engineering requirement. Further confusion is introduced through variations in pin-pointing locations where axial compression in the work strings should be checked for mechanical integrity. A simple and yet rigorous mathematical model is essential for adequate prediction of axial compression profiles in work strings for ERD. This article presents a simplified tubular mechanics model for describing axial force transfer under ERD conditions. We discuss the model in finding the point of peak compression in casing strings. This point is predicted to be in the arc section near the heel of a horizontal wellbore, under borehole drilling, and casing running conditions. The exact location of the peak axial compression changes with pipe-wall friction coefficient. For the friction coefficient in the range of 0.15 to 0.35, this point occurs in the range of inclination angle between 70.7 o and 81.5 o , averaging 76.1 o . The model can also be used for other purposes, including prediction of depth limit, bottom hole assembly (BHA) design, and locking up analysis of coiled tubing (CT) strings.

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Section: Introductionmentioning

confidence: 99%

An Analytical Model for Axial Force Transfer and the Maximum Compression Point of Work Strings in Extend Reach Drilling

Shaibu

2020

IMST

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Designer Directional Drilling to Increase Total Recovery and Production Rates

Eck-Olsen¹,

Samuell

Reynolds

1994

IADC/SPE Drilling Conference

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SPE and IADC Members Abstract The implementation of a new type of well profile. the designer profile, has resulted in increased recovery and production rates. The geologically complex Gullfaks Field (See fig. 1), located in the Norwegian sector of the North Sea, has seen significant change in the initial field development plan (FOP) as a result of the design technology. A new type of well profile was necessary to increase both total recovery and production rates from Gullfaks platforms A, B and C. Advances in steerable technology and directional drilling performance enabled a three dimensional horizontal I extended reach well profile, now designated as a designer well, to be utilized to penetrate multiple targets. This paper presents the concept. motivation, performance, results and conclusions from four designer wells used in the revised FDP. Introduction The Gullfaks Field, block 34/10 (See fig. 2) in the Norwegian sector, is the first license ever run by a fully Norwegian joint venture corporation. The license group consists of Statoil (operator), Norsk Hydra and Saga Petroleum. The field currently produces more than 85,000 5m /day of oil from three main reservoirs of the Jurassic age. The field produces from three separate Condeep (OBS) platforms; Gullfaks A, B and C. Gullfaks A and C are fully independent processing platforms with three separation stages. The Gullfaks B platform provides processing facilities for single stage separation only and transfers oil to both Gullfaks A and C for further processing. The Gullfaks Field has a very complex reservoir with numerous fault blocks and structures. Reverse faulting, in areas dominated by normal faults, accentuates the complexity of this reservoir. To date, approximately 70% of all GulIfaks wells have encountered small-scale faults not previously detected by seismic imaging, which again adds to the challenge presented by this field. Approximately 100 wells will be necessary to properly develop the Gullfaks Field according to the FDP. Generally, two producing wells are accompanied by one injector well. With the initial FDP approved in 1981 and an updated FDP approved in 1985 it is easy to understand its revision in light of the combination of technological advances and increasing knowledge of the reservoir with each well drilled. MOTIVATION FOR NEW PROFILE The initial FDP was based upon well profiles with minimum displacements of 3 km and maximum inclinations of 60. As the early production levels were below expectations, concern existed regarding future production levels on Gullfaks wells. Optimized multiple targets and optimized borehole placement were felt to be critical to improving the production rates and total recovery on the Gullfaks Field. To optimize both the targets and borehole placement, in this geologically complex field, would require substantial turn in the horizontal plane. The drilling department expressed concern about the ability to drill highly deviated wells with large turn in the horizontal plane. As steerable technology improved and the level of execution of the directional companies providing steerable motors improved as well, both management and the geology department were increasingly confident that this type of well profile could indeed be drilled successfully. P. 255^

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Steerable Rotary Drilling With an Experimental System

Barr

Clegg

Russell³

1995

SPE/IADC Drilling Conference

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SPE Members Abstract Some of the needs in directional drilling of extended reach and horizontal wells are discussed. It is forecast that Steerable Rotary Drilling (SRD) will meet some of these needs, providing economic benefits. Known options for an SRD system are briefly discussed. The system devised uses synchronous polyphase modulation of bias from a mechanism connected to, and rotating with, the drill bit, powered by drilling fluid and controlled by a directional sensor package, the orientation of the latter being independent of 8HA rotation, stabilized and controlled. This scheme meets structural requirements while being capable of development for a wide range of hole sizes The concept was proved by drilling an interval of 638m (2092ft) with an experimental SRD system. Deviation, while rotating, was controlled at rates up to 8.50/30m (8.60/100 ft) to change elevation up/down and azimuth left/right. The system was successful with both PDC and roller cone bits and the deviation rate vector was largely independent of bit weight. rotary speed and penetration rate. The drilling trials have provided data for a product aimed particularly at extended reach and horizontal drilling. Economic benefits are expected by saving time and by improving directional control. INTRODUCTION. Trends in directional drilling. Benefits of Extended Reach and Horizontal drilling. In developing drilling techniques, attention has traditionally been focused onto reducing "cost per foot". This is only one component of the more fundamental economic target of reducing cost per barrel. In recent years, the economic benefits of extending lateral reach capability in deviated drilling have been clearly recognised. In some cases, it is even feasible to develop offshore reservoirs from land, eliminating costly offshore platforms. The potential benefits of fewer platforms are illustrated by examples of savings quoted of $183 million in Wytch Farm, Southern England, and up to $100 million at Pt. Pedernales, offshore California. A related development is that of horizontal drilling. This can also reduce the cost per barrel, despite the higher cost per foot and feet per well. Extending lateral reach capability of deviated (including horizontal) wells depends on several interacting critical technologies. These have been widely reviewed, for example, by Payne, Cocking and Hatch, who also give many other relevant references. P. 435

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North Sea Advances in Extended Reach Drilling

Cited by 5 publications

References 0 publications

An Analytical Model for Axial Force Transfer and the Maximum Compression Point of Work Strings in Extend Reach Drilling

An Analytical Model for Axial Force Transfer and the Maximum Compression Point of Work Strings in Extend Reach Drilling

Designer Directional Drilling to Increase Total Recovery and Production Rates

Steerable Rotary Drilling With an Experimental System

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