Between 2005 and 2010, three major events led to a significant increase in design demands of deepwater field developments in the Gulf of Mexico (GoM):Category 5 hurricanes Katrina and Rita (2005),The Macondo well blowout (2010), andThe development of deeper, tighter, more remote reservoirs These events have resulted in increased metocean criteria, new safety regulations and functional requirements associated with producing deeper, higher pressure and lower porosity reservoirs. This paper will examine and contrast the design impacts on Tension Leg Platform (TLP), Semi-submersible and Spar floating platforms before and after these events. The overall impact of these new requirements on topsides, hull, station-keeping and riser systems of recently sanctioned TLP, Semi-submersible and Spar platforms will be compared with pre-2005 sanctioned platform analogues to demonstrate the resulting impacts on platform size and cost. Increased demands of post-2005 sanctioned GoM floating platforms have resulted in higher deck elevations, greater topsides payload, more robust station-keeping systems and larger hull displacements. Further, the feasibility of proven risers and well systems is challenged by the higher wave induced motions associated with greater design and survival sea-states and high pressure reservoirs. The design impacts of pre- and post-2005 sanctioned TLPs (Mars A, Olympus), Semi-submersibles (Atlantis, Jack St. Malo) and Spars (Tahiti, Lucius) on topsides, hull, station-keeping and riser systems will be compared and differences explained. This paper will enable Operators and platform designers to:Appreciate the magnitude of impact on size and cost of floating platforms of post-2005 requirements,Understand the relative impacts on the three major hull types commonly used for GoM developments, andUpdate analogues and norms used in benchmarking and concept selection

Successful deepwater field development planning requires close collaboration between the subsurface, drilling and completions, surface facility, operation and business teams that jointly constitute the development planning team. The reservoir is the main driver of the development plan. Despite significant technological advances in reservoir characterization, there remains a high degree of uncertainty in predicting well performance and recovery. This is attributable largely to the very high cost of deepwater drilling exploration and appraisal of deep reservoirs which limits the data set of key parameters required to construct the reservoir and geologic models. The development planning team must quantify and manage this uncertainty to mitigate the potential for an over or under designed surface facility.

ThHp@wwnaaidulh xpmMt?hm byh OTC Prmun COmmitbafbldldw-*: intomdm conbimd h q qbdm21wbfniltd by* qlhr(s) Cmk19 ,h-f@bDM~Wti~TA~~qd qm wbji% b mlTOamby thOauthO@?? mma@dmI,. p-aantd, donnd -* r86u4 qy pM4tand tiohhww TdmdcQycanfwwH cfIb 0ik.f8Pwmm8i0n k.cOpy m mmktdmm abanadnotmmlhm 3Wwnth Ilbmuum lnaynd Lmmpkd Tha qbdmd should m-m wnspwnm MmwlOdgmnt dw+mmandbywiwnttm ppwm W-@ ABSTRACTWorldwide, operators are focusing efforts on deep water prospects in their search for new oil and gas discoveries. In the US Gulf of Mexico, Tension Leg Platforms (TLP) are drilling and producing in 800 meters water depth and developments in even deeper water are underway. Current TLP technology can be extended to approximately 1,500 meters, but in order to make developments at such water depths (and deeper) economical, new and imovative solutions are required to reduce costs and shorten development schedules. The 3 cohunn TLP design described in this paper satistks such requirements. The concept features a simplified and cost effective tendon system and a modularized deck design utilizing a "splash zone truss".

Tanker Based Floating Production Storage and Offloading Systems (FPSOS) are an important component in developing marginal and remote offshore oil fields. This paper provides insight and guidance to operators and designers faced with the many complex issues and tradeoffs involved in selecting a cost-effective FPSO for particular field development conditions. A historical review is included that traces the evolution of the concept from the first installation in 1976 to the present. Useful statistical data on past, present and planned FPSOS is provided. Design drivers, such as production data, service life, site conditions and statutory/regulatory requirements References, figures and tables at end of paper. 221 are discussed. Major selection issues, which include vessel size, type (newbuild or conversion) and mooring system type, and the factors that affect their selection are presented. A case study for a hypothetical field development illustrates a systematic approach to the selection and design of a costeffective FPSO.

This paper provides an overview of the current state of deepwater technology. It discusses the major factors that must be considered when evaluating potential deepwater development concepts, presents proven deepwater development concepts, and provides insight into the applicability of each. Two unproven "dry tree" concepts are presented to illustrate proposed new concepts. Approximate costs are included, leading up to general conclusions with respect to the evaluation process. The focus is primarily on the Gulf of Mexico.