Deepwater opportunities exist around the globe. Beyond the commonality of water depth however, each opportunity comes with its own unique set of requirements. Providing deepwater services worldwide demands flexible processes and the ability to develop and deploy a variety of development systems. SIEP Inc. provides deepwater services to Shell's Operating Units around the world. SIEP has three deepwater projects currnetly underway, each employing a different surface structure. In addition, innovative new generation production systems are under development. This paper will look at the various configurations, and explore the technical and economic issues key to their selection. Introduction Successful deepwater development depends on an experienced team using a systems approach to select a field development concept. Although this paper will focus on surface systems, a systems approach to production system selection must integrate subsurface and surface expertise. The maturation of subsurface understanding must keep pace with surface system selection so that development systems can be based on reasonably mature characterization of a prospect and thus permit estimation of overall prospect value. Estimation of prospect value in terms of relevant performance indicators is the key to selection of a good development option. In addition to the basic requirement of subsurface and surface integration, all surface systems including well delivery, subsea systems, flowlines, structural systems, facilities, export and operations must be considered simultaneously. To be done well, experienced technical staff with the proper tools are required. Improvement in performance results when the staff is in a position to transfer knowledge from one project to the next. Realization of the need to assemble multi-disciplined teams and to build from project experience led Shell to form Deepwater Services (SDS). This organization provides technical support to Shell operating units world-wide that have interest in deepwater acreage. Providing deepwater services around the world demands flexible processes and the ability to deploy a variety of development systems. Key Performance Indicators Identification of key performance indicators or measures of goodness is perhaps the most important aspect of successful system selection. Typical performance indicators are:Financial value to operatorTime to first productionFinancial value to other stakeholdersFinancial exposureAdaptability (the ability to deal with uncertain fluids, rates, temperatures, etc.)Sustainability (Domestic content, local impact, energy efficiency, etc.)Strategic or infrastructure valueRobustness (the ability to respond to resource uncertainty) Financial value to the operator and partners is frequently the primary indicator of system performance. A broader set of indicators will generally be necessary for optimal system selection. Once these indicators are chosen a process must be established for each indicator that can measure the performance of a system in a way that can be used to compare options. Strategic Position Identifying a strategic or philosophical position with regard to trade-offs that generally have broad or fuzzy optima is also an important part of successful system selection. These trade-offs include:CAPEX vs. OPEXStandardization vs. ImprovementProven Technology vs. Innovative TechnologyMinimum Capacity vs. Future Capacity

The Enchilada platform was designed as a central Hub for numerous pipelines in the Garden Banks area of the Gulf of Mexico. A new approach was developed to bring these pipelines up to the platform deck. The Enchilada platform was designed for 17 pipeline connections and as many as 23 pipelines were considered during the design. This large number of pipelines required either a new approach for the pipeline connections or the use of a jacket structure with more main legs. The four main legs of the Enchilada jacket did not have sufficient space for conventional individual or bundled pulltubes. The approach developed for Enchilada was to bring all pipelines up to the deck within the conductor guide framing through vertical pipeline bundles nicknamed CONSPUB's (Conductor Supported Pulltube Bundle). The CONSPUB's are vertically supported near the base of the jacket and require only lateral support at each guide elevation. The vertical portions of the CONSPUB's are field installed, which defers costs for future pipelines. This paper describes the designdetails used for the Enchilada design and discusses alterative details that may also be used. Benefits of this approach are discussed including cost savings and future pipeline flexibility, The CONSPUB approach described in the paper will provide designers with an alternative to conventional leg supported pulltubes and risers. Introduction The overall field development strategy in Garden Sanks Blocks 128 and 172 is described in Reference I. The Enchilada platform was designed as part of this field development and was planned as a central Hub for numerous pipelines. Prior to the decision to design the Enchilada structure as a Hub, the Enchilada platform was planned as a minimal stand-alone facility for drilling and production. The original jacket design concept consisted of a four-leg jacket to be installed in two lifted pieces and joined in-place offshore. The two-piece lifted jacket concept offered significant cost and schedule advantages2 and it was preferred to utilize the same concept even with the higher functional requirements of a hub, specifically a large number of pipelines. The final platform was designed for 17 pipeline connections and as many as 23 pipelines were considered during the early design. Conventional pulltubes are supported along the main legs of the jacket. Incorporating 17 pulltubes would have caused significant congestion of the four main legs of the planned Enchilada jacket. The design team concluded that the four-leg jacket structure did not have sufficient space for conventional individual or bundled pulltubes. A new approach was developed to bring these pipelines up to the platform deck. This approach was to bring all pipelines up to the deck within the conductor guide framing through vertical pipeline bundles nicknamed CONSPUB's (Conductor Supported Pulltube Bundle). The vertical portions of the CONSPUB's can be field installed, which defers costs and eliminates lift weights of the future pipelines. The deferred weight was an important factor for the Enchilada jacket, since the lift weight of the jacket sections were near the capacity of the offshore construction vessel cranes. Deferring costs improves the profitability of the project and avoids pre-installing components that may never be used.

A new type of jacket design was developed for Shell Offshore Inc.'s Enchilada platform located in the Gulf of Mexico in 630 feet of water. The design was developed by an integrated team representing the operator and contractors and was based on utilizing specific contractor equipment and procedures in order to lower costs and reduce cycle time. The jacket was designed for installation in two sections that were joined underwater with a grouted connection. Both jacket sections were lifted from transport barges and installed on location with HeereMac's SSCV Balder. The installation method avoided the typical launch framing required for jackets in this water depth. Launch framing accounts for as much as 25% of a typical launched jacket weight. This paper describes the unique features and important aspects of the project, including contracting, design approach, fabrication, and installation. The development of this platform concept has added an alternative to conventional single piece launched jacket designs for water depths in the 500 to 700 foot range. Results are presented showing the steel weight savings and the schedule reduction enabled by the design. Information provided in this paper will allow designers and planners to evaluate this alternative design concept. Introduction The Enchilada platform was designed as a fixed structure in 630 feet of water in the Gulf of Mexico. The overall field development strategy in Garden Banks Blocks 128 and 172 is described in Reference 1. The primary challenges of the platform design and construction were to reduce costs and lower design to construction cycle time. The design practice for fixed offshore structures is well established. In recent years, designs have steadily produced significant cost and schedule improvements. The challenge of producing further improvements on the established fixed platform design practice requires innovation, risk taking, and new design approaches. During predesign studies for the Enchilada development, a novel design approach and design concept were identified by a team consisting of engineers from Shell, Aker Omega, Aker Gulf Marine and Heere Mac. The design approach utilized an integrated design team to develop a new type of design taking advantage of existing contractor equipment and procedures. The design concept included a two-piece lifted jacket that was joined underwater with a grouted connection. Platform Functional Requirements The Enchilada platform was designed for topside facilities capable of processing 60,000 barrels of oil per day and 400 million cubic feet of gas per day. The total topside operating weight is approximately 9,000 tons with an initial dry lift weight of 4,000 tons. The platform will support 15 production wells and 17 import/export pipeline risers. The export pipelines will be capable of transporting over 1 billion cubic feet of gas per day and 250,000 barrels of oil per day (some of the pipelines import production from nearby fields). Predesign Studies Preliminary design activities were initiated in November of 1994. With substantial contractor involvement, preliminary designs were developed for both a single piece launched jacket and for the two-piece design that was ultimately chosen. In addition to the preliminary structural design, cost and schedule estimates were developed. At the same time, a preliminary design was developed for the deck and facility.

TX 75083-3836, U.S.A., fax 01-972-952-9435. Abstract • Description of the Proposed Paper:A variety of project management models and strategies can be utilized for deepwater projects and the selection of which model is most appropriate for a project is critical for the success of that project or venture. The project execution strategy and the project management model should be designed and planned based on the unique features and attributes of the project such as: specific country or area contracting restrictions; past project experience of similar scope; the level of definition of project scope; capabilities and experience of available contractors; the use of new technology; requirements for local content; and other unique risks or uncertainties. This paper will discuss different project management models and the key parameters that define these models as well as provide insights into the pros and cons of the project management models that were used. • Application:Operators in various areas of the world including Brazil can use the results of this review to identify potential future project management models that can be selected based on their specific project attributes. • Results, Observations, and Conclusions:Different project and venture management models will be discussed and guidelines will be provided for selecting the best model for a range of projects and their associated attributes. Views on future successful project management models will be offered based on the lessons learned from the review. • Significance of Subject Matter:The paper should be of interest to managers in the planning phase of future projects.

A.S, Bangs, Hudson Engineering Corp., and D.G, Morrison, Shell E&P Technology Co., and P.L. Dorgant, Shell Offshore Inc. Ccwnehl190s.OFFSIWIE TECHNOLOGY CONFERENCE ?IWIpqw WM Awt.d tar ProsontatkYII by Iho OTC Program~oa Wowng rww d mfomwon cantawd in an abslrad subnmmd by H!. mahof(s Commwsd VM paw q pfawnDd,hwDn c4bs0nrcww sdbyth90tbh omTodm0@y &l UOna qnd-o Wbpd to d!.o.sti,tio&,M.r-w..m. P-*mto$#y%2&y'& OYrmd(a! byti tiha s) TIu INIOMI. a PWII@, dca II@abwsa d not mom thm 3M wrds Illustratw!anw nol k cdad. AbstractThe API RP 2A 20ttt Edition allows for dwtionality in wave loading, with the wave height in the minimum direction as low as 70% of the wave height in the maximum direetion. The resulting statically applied loads may differ by as much as 50% from the maximum to the minimum wave directions. This paper deseribes the finding that dynamic directional wave loading design according to API IV 2A can result in much larger than expected loads along the "reverse" direction to that of the major wave heading, Rigorous random wave analyses on jackets in 600 to 900 ft water depths using RP 2A and accounting for dynamic structural behavior, revealed significant "rebound" (opposite to major wave heading) inertial Ioadng. These rebound loads were targer than the apptied loads from the minimum wave specified by RP 2A directional criteria. Results quantify and explain the components of the rebound load. This paper develops a practical recipe, using RP 2A, that accounts for dynamic structural response. The design procedure is verified with rigorous random wave analysis results Recommended Praclice jor Planning, Designing, and Constructing Offshore Platforms, 1993, API RP 2A 2(Ms Edition, American Petroleum Institute, Dattss, Texas. Kint, T. E., and Morrison, D. G., 1990, "Dynamic Design and Analysis Methodology for Deepwater Bottom-Founded Structures". Proceedings of Ihe Twerrly-Second Offshore Technology Conference, OTC 6343, Vo]. 2, 607-614, Houston, Texas.