Summary The Jubarte field, in the Campos Basin, Brazil, was discovered in January 2001. It is located approximately 80 km offshore from the State of EspÍrito Santo, under water depths between 1,000 and 1,500 m, containing oil of 17°API and viscosity of 14 cp at reservoir conditions. This work presents a review of the artificial lift and flow assurance aspects faced by PETROBRAS in the exploitation of Jubarte heavy oil, starting from the features of the pilot phase. It details all the challenges posed and innovations proposed and implemented for Phase 1 field development, as well as expectations for the subsequent Phase 2. Previous ESP Experiences and Applications At the end of 1992, PETROBRAS discovered significant reserves of oil in deep waters, in the Campos Basin, Rio de Janeiro. From these discoveries of new research programs for developing new deepwater installation technology, floating production unit systems had been considered for directly receiving subsea satellite well and manifold production (Ribeiro et al. 2005). The efficiency of an ESP system is not adversely affected by distance from the well to the host platform, as is the case with other forms of artificial lift. Tests have determined the feasibility of ESPs in subsea wells as far away from the host platform as 20 km or greater. ESPs are highly efficient and evolving ESP technology is enabling distant located wells to be tied back to a host platform, making marginal and distant fields economic to exploit (Anderson et al. 2001). At that time it was concluded that the best production system alternative for the RJS-221, the first subsea well installation of the world, was through an ESP pump whose rotation of the electrical motor could be controlled by a frequency variation driver (VSD). The RJS-221 ESP prototype system installation approval came together with the signature of a Technological Cooperation Agreement with six companies (Reda, Lasalle, Tronic, Pirelli, Cameron, and Sade-Vigesa) in March of 1994. In October of 1994, an ESP operated for the first time in a subsea well. This ESP, installed 1900 m below the sea soil in the RJS-221 well, was controlled from the fixed Carapeba 1 platform, which was located 500 m from the well. The oil was pumped through 15 kilometers of lines from downhole to the Pargo platform, 13.5 km from the Carapeba 1 platform, where it was joined with the oil lifted through the ESP method from other platforms. The oil was flowing through the Carapeba 1 platform, acted as a manifold, because no transference pumps were available in this platform (Ribeiro et al. 2005). A production level analysis comparing the gas-lift and the ESP method costs over a 10-year period found non-failed operation for the gas-lift method over a 5-year period, and 2 years without failure for the ESP method. That analysis demonstrated feasibility for the ESP method, especially for the Albacora field, and that it was not only important to increase the non-failure operation time, but also to reduce the intervention costs of the ESP system. This led to the development of a new horizontal wet Xmas tree for the ESP installation of the RJS-477 well (Mendonça 1997).
Summary Length–weight relationships (LWRs) for 35 freshwater fish species from the SP/RJ coastal basin in Brazil are presented in this paper. Fishes were captured between 2011 and 2015 on an irregular basis using electrofishing, sieves, trawl nets, cast nets and fish‐traps. In this study new LWRs are reported for 28 species, plus the total weight and length for 34 and nine species, respectively. The study provides new information on less‐studied species and can serve as a basis for management and conservation in this area.
Integrated operations systems have been consolidated as an important management tool in the global oil industry. In this context, considering the objectives of reducing operating costs and investments, increasing recovery factor and, therefore, increasing production efficiency, Petrobras has begun to implement the Integrated Operations Management (GIOp) as a supporting element to achieve the long term goals of the company, as established in its 2020 Strategic Plan. The GIOp is an initiative of the Exploration and Production (E&P) branch at Petrobras. This initiative is guided by the articulation of technical disciplines and companies involved in operational activities, focusing on the proactive role, bringing quality and comprehensive view in the planning of operations. Its implementation is occurring in the operational units of the south and southeast regions of Brazil, an area that responds for more than 80% of national oil and gas production. As in other operating units of the Petrobras E&P, Operations Unit of Espírito Santo, responsible for the management of production assets in the Campos and Espírito Santo basin, began the process of GIOp implementation through pilot projects. The results obtained so far are considered positive; however, beyond all the technical challenges observed for system implementation, it is noteworthy emphasizing the importance of managing people in the process, an element that has been confirmed as relevant in the GIOp implementation of one of the pilot projects. This paper aims to highlight the main challenges in managing people for the implementation of an integrated operations system and to present the case study of the early implementation of GIOp in the Jubarte and Cachalote Asset, whose production fields are located north of the Campos Basin.
TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe Jubarte field, in the Campos Basin, Brazil, was discovered in January 2001. It is located about 80 km offshore from the State of Espírito Santo, under water depths between 1,000 and 1,500 m, containing oil of 17 °API and viscosity of 14 cP at reservoir conditions. This work presents a review of the artificial lift and flow assurance aspects faced by PETROBRAS in the exploitation of Jubarte heavy oil, starting from the features of the Pilot Phase. It details all the challenges posed and innovations proposed and implemented for Phase 1 field development, as well as expectations for the subsequent Phase 2.
The Jubarte Field, off the Espirito Santo State coast, Brazil, is an offshore heavy oil deepwater field that poses several challenges. It was discovered in January, 2001, at about 1,300 m (4,400 ft) water depths, and its reserves mount to 700 million barrels of 17 API oil. Before its commercial production, several questions remained to be answered, such as the well productivity, the best artificial lift method and the recommended production strategy. In order to fully understand and implement a solid definitive production system, PETROBRAS has decided to develop the field step-wise, starting from a two-month extended well test, then a Pilot Production phase, followed by two development phases, named Phase I and Phase II. The Phase I system includes FPSO P-34, with a plant adapted to produce 60,000 bpd of heavy oil in deep waters and four horizontal production wells. In this phase, PETROBRAS is piloting several new technologies, regarding artificial lift, to be used in the final Phase II development and other PETROBRAS demands. High power downhole ESP installed through horizontal wet X-tree and seabed installed ESP systems are among the major innovations. FPSO P-34 has a site where PETROBRAS Research Center - CENPES - will test new technologies of heavy oil and water separation. Phase I started production in the 4th quarter of 2006, and it is expected to provide rich information regarding aquifer strength which will optimize the water injection system of Phase II. For Phase II, in addition to the technologies tested in Phase I, other innovations are anticipated for the processing plant of the 180,000 bopd FPSO, specifically designed for heavy oil production. Phase II first oil is expected in 2011. The process plant solution is presented considering free water knockout separator, oil stabilization on the oil dehydrator, the FPSO arrangement and main utilized facilities. The technological solution to assure the oil quality is discussed. This paper describes in details the technology gaps identified and the solutions on the works for making this heavy oil production system, in deep to ultra-deep water, a successful business. Introduction The Jubarte Oil Field, discovered in January 2001, is located approximately 80 km off the Espirito Santo State coast, southeastern Brazil (Figure 1), under water depths between 1,000 and 1,500 m. Figure 1 - Jubarte Oil Field location map (available in full paper) The Jubarte field contains 17.1° API oil, with dead oil viscosity of 3,000 cP, at 20°C. It's the most viscous oil at surface conditions ever produced in Brazil through a wet completion system. Such fluid characteristics and the expressive discovered volumes in this area were considered as a big challenge and an opportunity to develop knowledge to exploit heavy offshore oil reservoirs in deep waters under economical basis. Thus, several questions should be addressed such as the well productivity, the best artificial lift method and the aquifer strength. In order to answer the main questions, PETROBRAS has decided to start an Extended Well Test, beginning in October 2002.
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