Petrobras and partners have been developing Brazilian Santos Basin Pre-Salt ultra-deepwater areas through the use of Floating Production Storage and Offloading Units (FPSOs), equipped with topside facilities designed to receive produced fluids and process them to generate end streams to export and injection. The large hydrocarbon volumes in Santos Basin Pre-Salt areas, which have been successively confirmed by the results of exploratory and productions wells, have encouraged Petrobras and partners to choose an aggressive development strategy over a more conventional one. Based on this decision, FPSOs were chosen, mainly due to crude oil storage capability thus not requiring the construction of long-length oil pipelines, and also because of other characteristics that allow a short term completion with economic advantages. Therefore, the topside process plant conceptual design had to deal with uncertainties in the reservoir fluid compositions and production profiles. This means a wide range of CO2 and H2S contents, oil API gravity, flow rates and arriving fluid pressures and temperatures, in order to guarantee an adequate nominal capacity and turndown, and also the proper performance within the established design cases. The main purpose of the topside facilities is to gather and treat the produced fluids to be sent ashore. The treated oil is routed to cargo tanks, the produced water is treated and discharged overboard, an dthe bulk treated gas stream is exported through a gas pipeline network, which allows to send the stream to three different gas processing sites onshore. The separated CO2-rich stream is injected back to the reservoir. Besides the production units specially designed for Santos Basin Pre-Salt features, some Pre-Salt reservoirs from Campos Basin have been also being produced, by connecting new wells to existing production units. The main approaches regarding these units and its production in Campos Basin Pre-Salt are also part of the scope of this paper. As a result of these different strategies and due to the daily efforts to overcome the forementioned challenges, more than six hundred thousand barrels per day of crude oil, as a monthly average, have been produced in Brazilian Pre-Salt areas, after only eight years since the early developments of the area.

This paper describes the current studies to define alternatives for the geological storage of the CO2 present in the associated gas to be produced from the Pre-salt reservoirs of the Santos Basin, Brazil. Recent hydrocarbon discoveries in Santos Basin, offshore Brazil, in the so-called pre-salt reservoirs, brought many challenges for the production development (Beltrao et al., 2009). The reservoirs are heterogeneous microbialite carbonates, located below up to 2,000 m salt layer thickness, in water depths of 2,200 m. The oil is a 28 – 30°API, with GOR higher than 200 m3/m3. Besides the unique environment, one additional challenge is the variable CO2 content in the associated gas. The sustainable hydrocarbon production from the pre-salt reservoirs will, then, require, in line with Petrobras and its partners' vision, avoiding emissions of the CO2 produced together with the hydrocarbon. The task that would be difficult for onshore oil fields reaches unparalleled complexity in the subsea completion deep water production scenario. Some alternatives are under study for the CO2 capture and storage: reinjection in the producing reservoirs, in salt caves, in salt water aquifers, in depleted gas reservoirs and even transportation and use of the CO2 for industrial purposes. Although still in the early stages of development, work done so far paved the way for robust and sustainable gas processing and CO2 separation, compression and reinjection in secure sub surface geological horizons. The current analysis indicate that the best alternative seems to be the reinjection in the oil producing reservoirs, with a good perspective of enhanced oil recovery by the association of gas and water injection in the Water Alternating Gas (WAG) process.

O objetivo do trabalho foi analisar as mudanças históricas da linha de costa e, verificar a eficiência de faixas de recuo em praias arenosas, estuarina e oceânicas, localizadas no sul de Sergipe, nordeste do Brasil.  A metodologia consistiu na determinação da taxa de variação e do comportamento da linha de costa (1971 a 2017), e na análise de eficiência do uso de faixas de recuo para construções leve e pesada, caso tivessem sido implementadas em 1971. As praias estuarina e oceânicas em erosão apresentaram taxas médias de -5,6 e -1,6 m/ano, respectivamente. O comportamento erosivo da linha de costa ocorreu em 82,4 % da praia estuarina e em 38,6 % das praias oceânicas. A análise da eficiência das faixas de recuo para construção pesada mostrou que se tivessem sido implementadas em 1971, muitos dos danos às estruturas antrópicas teriam sido evitados. No entanto, a metodologia adotada foi inadequada, por não considerar o tempo de análise (curto, médio ou longo prazo). O uso da taxa erosiva verificada em cada localidade multiplicada pelo tempo desejado parece ser a alternativa mais viável na ausência de outros dados. Este estudo demostra que um método simples pode ser usado com sucesso. Palavras-chave: linha de costa, mudanças históricas, taxa de variação, análise da eficiência.