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Abstract As more subsea projects mature and with increasing understanding of operations involving subsea wells, the industry is constantly faced with the constraints and challenge posed by the requirements for metering, sampling, well testing and allocation. These challenges are even more pronounced in cases where flow assurance issues play a role especially for long tie-back systems. Current regulation in the Nigerian sector has yet to catch up with these developments and as such operators struggle to meet the requirements. A number of possible solution to the seeming problems or issues are under study, and with updated knowledge of the systems, it has become imperative to articulate and formulate strategies and philosophies for resolving or addressing the metering challenge for operations in Deepwater Nigeria. This article analyzes one of such solution in the application of subsea multiphase flow meters Introduction Subsea systems have evolved over the years, as a major solution to the technical and commercial challenge of harnessing reserves in the deepwater terrain. With the ability to extend tie-back distances, it affords a perfect means of achieving hub strategies allowing for continual development of reservoirs at great stepout distances. As stepout distances increase so does the challenge of delivering the hydrocarbon to the host facility. Flow assurance issues are key and often compounded by unwanted deposition such as hydrates, wax, scale and asphaltenes in the transportation and processing system components. This makes the task of measuring and quantifying the volumes of hydrocarbon products difficult. The traditional method is to measure these product quantities at the host, via test separators. The accuracy of the flowstream measurements is however a function of the stability of the system, requiring the introduction of artificial lifting systems (in most cases riserbase gaslift is employed). Operational experience with subsea production testing reveal that there are threshold rates required for stability. Below these threshold, serious system upsets such as slugging, impacts on the production system sometimes causing a shut down of the facility.
- Africa > Nigeria (1.00)
- Africa > Angola > South Atlantic Ocean (0.47)
- Africa > Nigeria > Gulf of Guinea > Niger Delta > Niger Delta Basin > OML 118 > Bonga Field (0.99)
- Africa > Angola > South Atlantic Ocean > Kwanza Basin > Kizomba Project > Kizomba C > Block 15 > Kizomba Field > Saxi-Batuque Field (0.99)
- Africa > Angola > South Atlantic Ocean > Kwanza Basin > Kizomba Project > Kizomba C > Block 15 > Kizomba Field > Mondo Field (0.99)
Abstract A business case to determine the economic value of deploying subsea intelligent well completions in a subsea development project deepwater West Africa has been developed. Deployment of smart well technology in the base case development of the case field provides an opportunity to develop 20% incremental reserves that would otherwise be uneconomical to develop without the ability to use a multizone completion solution. This results in a 50% gain (risked gain) in NPV for the project. The method is based on an analysis of possible completion failure scenarios, the probability of occurrence of these scenarios and the reliability of the downhole intelligent completion equipment. The cost analysis carried out, weighed the benefit of smart wells against conventional and stacking (commingling of zones) completion types. CAPEX was risked using Decision Tree analysis with data input from a wide range of data bases including fields in the Nigerian DeepWater blocks. Introduction For most subsea projects especially tiebacks, one of the development objectives is to optimize the tradeoffs between well construction costs and risks versus the level of subsea layout infrastructure required. The goal is to minimize development costs while maximizing subsurface flexibility and to effectively and efficiently develop all targeted reservoirs. One of such optimization strategies is the deployment of intelligent (smart) well technology. To unlock the full potential of intelligent wells, our understanding needs to be improved in two areas, firstly in determining the risked economic value of an intelligent well application (the business case), and secondly in operating an intelligent well to make optimal use of the enhanced functionality. This article addresses the first point and presents the benefit of deploying intelligent well completions in a deepwater subsea development with stacked reservoir. Background The field case study focused on a typical large oil accumulation development in a West African deepwater environment lying in 1000 - 1,500m (3,250 - 4,900 ft) water depth offshore. This field is to be developed as a subsea tieback to an existing FPSO (see figure 1).