Smiety of Petroleum Engineers. Ekctronb reprcduciion, distrtsition, or storsge of sny part of this paper for cwrnmem"sl PUPS without the kwitten mnsent of the Sceiety of Petroleum Engineets is prohibtied. Permission to reproduce in print is restricted to an abatrsct cf not more than WI words iluatrations may not be wpiad. The abstrsct must contdn conspicuous scknowfedgment of where and by whcm the paper ws presmtad. Wtite Librarian, SPE, P.O. Box 833835, Richardson, TX 75083-3336, U.S.A., fsx 01-972-952-9435. AbstractGoodwyn platform wells produce up to 220MMscf7d of raw gas yiel~ng UP to 20,000 bpd of stabilised condensate. The high productivity of the wells has reduced the number of development wells needed to satistJ platform capacity with significant cost savings. This high well capacity was achieved through the early recognition of the reservoir inflow potential in the completion design and addressing the critical issues of erosional velocity, Iifecycle sand production, sub-surface and surface equipment integrity in a high flow, high stress environment. To maximise the well potential the erosional limit was extended based upon actual experience. The risk of sand production was managed through a philosophy covering sand prediction and its control during operation. Well hardware was tightly specified and qualified within the defined operating envelope. These solutions were applied to both the initial conventional wells and for the later extended reach horizontal wells. Results fkom Goodwyn wells demonstrate that actual performance match the targeted ideal and that the issues have been managed. This paper presents a systems approach to well design where technical and external issues are taken into consideration. It is a retrospective look at the issues addressed for Goodwyn well desi~with updates to include current techniques.

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Summary The Vincent project is an offshore oil field developed by subsea multilateral (ML) wells with sand control. This paper provides an insight into how completion practices were developed to maximize well productivity and how they were balanced against risks for constructing ML junctions. The fluids used for drilling and cleaning up openhole laterals can have a significant impact on well productivity in standalone-screen applications, especially with respect to sand-screen plugging. This paper details the development of openhole fluid selection and cleanup practices for completing long 7,000-ft+ horizontal laterals with standalone screens. The Vincent wells are more complex because of drilling trilateral wells that include two technology-advancement ML (TAML) Level-5 ML junctions requiring openhole connections. The paper identifies the key risks for installing the ML junctions in a weak formation, including risks imposed from cleanup practices. The paper reviews the lessons learned during execution, how the ML-junction installation risks were mitigated, and how the Vincent wells were delivered with a well-performance meeting expectation.

The Vincent project is a heavy offshore oil field developed by subsea multilateral wells with sand control. This paper will provide an insight into how completion practices were developed to maximize well productivity and how they were balanced against risks for constructing multilateral (ML) junctions. The fluids used for drilling and cleaning up open-hole laterals can have a significant impact on well productivity in standalone screen applications, especially with respect to sand screen plugging. This paper details the development of open-hole fluid selection and clean up practices for completing long 2000m+ horizontal laterals with standalone screens. The Vincent wells are more complex due to drilling tri-lateral wells that include two TAML level 5 ML junctions requiring open-hole connections. The paper identifies the key risks for installing the ML junctions in a weak formation including risks imposed from clean up practices. The paper reviews the lessons learned during execution, how the ML junction installation risks were mitigated and how the Vincent wells were delivered with a well performance meeting expectation.

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