Underbalanced Drilling and Completion of Sand-Prone Tight Gas Reservoirs in
Southern North Sea

Veeken, Cornelis; Velzen, Hans van; Beukel, J. van den; Lee, Hon Meng; Hakvoort, R.G.; Hollman, Frans; evans, charles; Okkerman, Jos

doi:10.2523/107673-ms

Cited by 5 publications

(2 citation statements)

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“…The preferred option in tight gas reservoirs might be horizontal well drilling in underbalanced conditions (Veeken et al, 2007).…”

Section: Longitudinal Fracturementioning

confidence: 99%

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Evaluating Factors Controlling Damage and Productivity in Tight Gas Reservoirs

Bahrami

2013

Springer Theses

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“…The preferred option in tight gas reservoirs might be horizontal well drilling in underbalanced conditions (Veeken et al, 2007).…”

Section: Longitudinal Fracturementioning

confidence: 99%

“…As an alternative option, long horizontal wells drilled in underbalanced conditions may increase lateral reservoir exposure to the wellbore with a minimized damage (Veeken et al, 2007).…”

Section: Introductionmentioning

confidence: 99%

Evaluating Factors Controlling Damage and Productivity in Tight Gas Reservoirs

Bahrami

2013

Springer Theses

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Southern North Sea Tight-Gas Field Development Planning Using Hydraulic Fracturing

Vos¹,

Shaoul²,

Koning³

2009

EUROPEC/EAGE Conference and Exhibition

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This paper presents an overview of the subsurface economic and technical issues involved in developing a Southern North Sea (SNS) tight-gas field using hydraulic fracturing. The paper investigates different kinds of wells (vertical vs. horizontal) and different completions; fracture spacing, fracture orientations (longitudinal vs. transverse).The investigation was performed using a range of different reservoir qualities with appropriate completion and stimulation designs. Production and Net Present Value (NPV) estimates were developed for the different scenarios for qualitative and quantitative evaluation. The result is a generic strategy to evaluate a Field Development Plan (FDP) using hydraulically fractured horizontal wells.The paper concludes with general guidelines on what type of recoveries are possible using different completion and stimulation solutions in situations with different kh distributions. The guidelines will help in initial screening of prospects to determine whether the tight gas reservoirs have significant potential for economic development. The latter is also a function of the actual development costs of pipelines and platforms, which is different for different companies and different locations. This paper also demonstrates why stimulation considerations should be put on the agenda early on in the construction of an FDP.

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First True Tight Gas (<0.1 mD) Horizontal Multiple Fractured Well in the North Sea

Schrama

Naughton-Rumbo

Bas

et al. 2011

SPE European Formation Damage Conference

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This paper describes the development of a tight gas reservoir in the Dutch sector of the Southern North Sea, using a horizontal well with 5 hydraulic fractures. The reservoir is tight (average permeability below 0.1 mD) and was discovered in 1986. The first development well was drilled as a long reach horizontal well in 1990, and completed with a cemented liner. The well was perforated and initial production was 0.2 mln Nm3/d after which the well quickly dropped below its liquid loading limit of 0.09 mln Nm3/d. The well was brought back into production 13 years later and produced at a stable rate of 0.07 mln Nm3/d. In 2005 the well was sidetracked using under-balanced drilling in an attempt to intersect natural fractures (Veeken, 2007). The initial production from this sidetrack was 0.1 mln Nm3/d, but this time the well was able to sustain production at 0.07 mln Nm3/d as the tubing head pressure was lower by that time. To develop this reservoir, the well was sidetracked (overbalanced) in 2008 and completed with a cemented liner. In 2009, 5 hydraulic fractures were placed using a jackup support barge and a specially converted supply vessel. Since December 2009 the well has produced steadily at 0.3-0.4 mln Nm3/day, a (steady-state) production improvement factor of 5-6. This was the first true tight gas (<0.1 mD) development in the North Sea using a horizontal well with multiple fractures. The initial production takes place at constant rate and constant pressure, which suggests that significant cleanup is taking place, either in the fracture or the reservoir or both. An attempt has been made to model this cleanup in a 3D reservoir simulation model. This paper describes the background of the project, fracture design methodology, operational issues and lessons learned, fracture treatment data analysis, post fracturing production analysis (with over a year of production history) and production forecast. This paper is a valuable case study for operators and contractors involved in offshore fracturing operations in low permeability gas reservoirs.

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Underbalanced Drilling and Completion of Sand-Prone Tight Gas Reservoirs in Southern North Sea

Cited by 5 publications

References 0 publications

Evaluating Factors Controlling Damage and Productivity in Tight Gas Reservoirs

Evaluating Factors Controlling Damage and Productivity in Tight Gas Reservoirs

Southern North Sea Tight-Gas Field Development Planning Using Hydraulic Fracturing

First True Tight Gas (<0.1 mD) Horizontal Multiple Fractured Well in the North Sea

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Underbalanced Drilling and Completion of Sand-Prone Tight Gas Reservoirs in Southern North Sea

Cited by 5 publications

References 0 publications

Evaluating Factors Controlling Damage and Productivity in Tight Gas Reservoirs

Evaluating Factors Controlling Damage and Productivity in Tight Gas Reservoirs

Southern North Sea Tight-Gas Field Development Planning Using Hydraulic Fracturing

First True Tight Gas (&lt;0.1 mD) Horizontal Multiple Fractured Well in the North Sea

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Product

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First True Tight Gas (<0.1 mD) Horizontal Multiple Fractured Well in the North Sea