Bigbore Well Completions: A New Completions Technique for Arun Field

Cannan, W.L.; McKenna, Dan; Sukup, R.A.; Calvert, D.G.; Quitzau, R.; Sardjono, S.; Ellison, P.C.

doi:10.2118/25384-ms

Cited by 12 publications

(1 citation statement)

References 7 publications

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“…The primary scope of the study was to review existing developments to understand field proven designs. The study focused on a global review 2,3,4,5,6,7,8,9,10,11,12,13,14,15,18 of ultra-high rate gas wells which included nine (9) areas and over 130 wells. 16 This study, combined with the experiential knowledge of the team, resulted in a design that integrated the field proven lower…”

Section: Feasibility Studymentioning

confidence: 99%

Design, Qualification, QAQC and Operational Performance of Completion Fluid, Reservoir Drill-in Fluid and Breaker - Tamar, Offshore Israel

Healy¹,

Sanford

Hopper

et al. 2015

Day 2 Wed, March 18, 2015

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A case history from Offshore Israel is presented that describes the successful delivery of five (5) ultra-high rate gas wells (ϩ250 MMscf/D) completed in a significant (10 TCF) gas field with 7 in. production tubing and an Open-Hole Gravel Pack (OHGP). Maximizing gas off-take rates from a gas reservoir with high flow capacity (kh) requires large internal diameter (ID) tubing coupled with efficient sand face completions. When sand control is required, the OHGP offers the most efficient as well as the most reliable, long-term track record of performance. A global study of ultra-high rate gas wells was made to select and finalize the design concept after which the commensurate engineering rigor was applied. This paper will highlight the design, qualification, Quality Assurance / Quality Control (QA/QC) and operational performance of the completion fluids inclusive of the Reservoir Drill-in Fluid (RDIF) and the breaker. Completion fluids are critical to the success and production efficiency of an OHGP. The completions were installed with minimal operational issues (Average NPT Ϸ4%). Production commenced on March 31, 2013. All wells have performed to expectations with maximum well rates up 340 MMscf/D.

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Section: Feasibility Studymentioning

confidence: 99%

Design, Qualification, QAQC and Operational Performance of Completion Fluid, Reservoir Drill-in Fluid and Breaker - Tamar, Offshore Israel

Healy¹,

Sanford

Hopper

et al. 2015

Day 2 Wed, March 18, 2015

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Design, Construction, and Optimisation of Big-Bore Gas Wells in a Giant Offshore Field

Clancey¹,

Khemakhem

Bene³

et al. 2007

All Days

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An extensive big bore gas well drilling and completions program is in progress to develop the giant North Field, offshore Qatar. Benefits of the big-bore concept, compared to the prior 7-in. monobore design, include reduced development costs by requiring fewer wells, and deferred installation of compression by providing higher flowing wellhead pressures. This is the widest known application of a big bore design in one single field and involves a large number of wells. Many of these wells are drilled and completed to date and believed to be among the world's most prolific gas producers. These are also the first offshore wells to incorporate big bore well design for large-scale field development and feature industry advances in equipment design and manufacture. An extensive system of detailed design review, equipment performance testing, and quality programs has been implemented to meet challenging project requirements for well reliability. The wells feature a tapered tubing design known as the "Optimized Big Bore" (OBB). This paper discusses the challenges of planning and executing these OBB wells. It reviews the initial OBB well design, anticipated North Field drilling challenges, critical equipment specifications, and design revisions resulting from optimisation efforts over the past four years. Introduction Discovered in 1971, the North Field of Qatar is the world's largest non-associated gas field, extending over 6,000 km2, and contains approximately 900 TCF of abnormally pressured natural gas. Development has taken place in several stages, commencing with initial production by Qatar Petroleum in 1991 to supply the domestic gas market. This was followed in the mid-to-late 1990s by RasGas Company Limited (RasGas) and other projects to provide LNG to export markets. More recently, the growth in global LNG demand has sparked much more extensive development. RasGas is responsible for the development of a large area of the North Field, covering more than 500 Km2, to provide natural gas supply for both new LNG trains and the growing domestic gas market. The RasGas expansion plan requires a large number of wells to be drilled in the period 2002 to 2010 from several new wellhead platforms. Production is from the massive Khuff carbonate formation, which includes several productive intervals (K1, K2, K3, and K4), situated at approximately 10,000 ft TVD. This would differ from the earlier projects of the 1990's that developed only a part of the Khuff reservoir. In total, RasGas will operate more than 90 wells producing a total of 8 Bscfd. Well deliverability from the K1 to K4 reservoirs is very high due to both formation quality, near initial reservoir pressure, and high net pay thickness. Non-hydrocarbon gas composition varies between the four Khuff intervals within each well and also across the field. Well designs evolved from packer / tubing completions intended to produce at 60 MMscfd in the initial Qatar Petroleum project, to high-rate 7-in. monobore wells in the first LNG projects able to deliver in excess of 100 MMscfd.1 However, it was recognized by RasGas and its major shareholders Qatar Petroleum and the former Mobil Oil (now ExxonMobil) that higher capacity well designs, capable of producing in excess of 150 MMscfd, could be suitable for the planned RasGas expansion projects. Although individual wells would be more expensive to construct, there were two significant advantages that would result in a more cost effective project. These would be:

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Design, Installation, and Performance of Big Bore (9-5/8 in.) Completions: Mari-B Field, Offshore Israel

Healy¹,

Sanford²,

Reeves

et al. 2012

All Days

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A case history from Offshore Israel is presented that describes the successful delivery of two (2) ultra high-rate gas wells (+200 MMscf/D) completed in a depleted gas reservoir with 9⅝ in. production tubing and an Open-Hole Gravel Pack (OHGP). Maximizing gas off-take rates from a volumetric drive gas reservoir that possess high flow capacity (kh) require large internal diameter (ID) tubing coupled with efficient sand face completions. When sand control is required, the OHGP offers the most efficient as well as the most reliable, long-term track record of performance. A global study of wells completed with 9⅝ in. production tubing ("big bore") determined that this design concept was feasible and deliverable in a short time frame while still maintaining engineering rigor. The paper will highlight key accomplishments within various phases of a completion delivery process for critical wells. The completions were installed with minimal issues (NPT≈ 9%) and have produced without incident. The wells are capable of +250 MMscf/D and are currently producing at +220 MMscf/D.

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Bigbore Well Completions: A New Completions Technique for Arun Field

Cited by 12 publications

References 7 publications

Design, Qualification, QAQC and Operational Performance of Completion Fluid, Reservoir Drill-in Fluid and Breaker - Tamar, Offshore Israel

Design, Qualification, QAQC and Operational Performance of Completion Fluid, Reservoir Drill-in Fluid and Breaker - Tamar, Offshore Israel

Design, Construction, and Optimisation of Big-Bore Gas Wells in a Giant Offshore Field

Design, Installation, and Performance of Big Bore (9-5/8 in.) Completions: Mari-B Field, Offshore Israel

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