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Building Brazil's Petroleumscape on Land and Sea
Published in Carola Hein, Oil Spaces, 2021
By the mid-2000s, Brazil started to benefit from the scientific and technological infrastructure it had built for several decades. In 2006, the discovery of the pre-salt oil region (extending from the coast of Espírito Santo to Santa Catarina) made Brazil a net exporter of oil.59 Thus, a new pattern of interaction between Petrobras and its large foreign suppliers such as Shell had started, in relation to the development of technologies applicable to oil exploration in offshore area.60
Ensemble-based machine learning application for lithofacies classification in a pre-salt carbonate reservoir, Santos Basin, Brazil
Published in Petroleum Science and Technology, 2022
Amir Abbas Babasafari, Alexandre Campane Vidal, Guilherme Furlan Chinelatto, Jean Rangel, Mateus Basso
Pre-salt carbonate rocks were deposited in the Santos Basin during the rift and post-rift stages (Barremian and Aptian ages). These rocks are linked to faulting, erosion, and uplift. During this time, normal and strike-slip faults in an extensional tectonic environment formed grabens and horsts. It resulted in distinct paleoenvironmental depositional conditions that produced a wide range of carbonate deposits, such as those seen in the Itapema and Barra Velha formations. (Saller et al. 2016; Alves et al. 2017; Ceraldi and Green 2017). Along with depositional and diagenetic features, these carbonate rocks exhibit a variety of pore types and heterogeneity. (Herlinger, Zambonato, and De Ros 2017, Chinelatto et al. 2020). The mineral composition and diagenetic process have a significant impact on the porosity patterns in carbonate rocks. (Herlinger, Zambonato, and De Ros 2017, Kassem et al. 2022). The diagenetic process and stress regime can produce a wide range of pore types. (Babasafari, Chinelatto, and Vidal 2022). The carbonate rocks of the Barra Velha formation in the Santos Basin exhibit calcite shrubstone and spherulites, in which magnesium and clay minerals are replaced, followed by dolomitization and dissolution (Herlinger, Zambonato, and De Ros 2017). As a result, evaluating the lithofacies types is considered a significant step of quantitative interpretation in the carbonate reservoir.
Weldability evaluation of X80 sour line pipe using a combination of thermal simulation and actual girth welding
Published in Welding International, 2022
Gilmar Zacca Batista, Leonardo da Paixão Carvalho, Fábio Arroyo
Recent pre-salt offshore fields have created a new scenario for pipeline design and construction in Brazil. In order to explore the petroleum of the pre-salt fields, it is necessary to transport the associated gas to the land for long distances, resulting in high operational pressures. The large diameter associated with the high design pressure and the impurities present in the gas requires high-strength steels suitable to operate in sour environments. The use of conventional grades up to API 5L X65 could lead to heavy wall pipes that are not cost-effective [1–3] and brings additional commercial and technical issues for onshore pipeline construction. Indeed, heavy wall pipes have limited suppliers worldwide, and post-welding stress relief heat treatment is mandatory during construction by the design code ASME B31.8 [4] when the pipe wall thickness exceeds 1.25 inches. The solution to getting over this challenging scenario is to apply high strength-steels X70 and X80 suitable for sour service. However, before using these materials in pipeline construction for sour gas exportation, it is necessary to analyze and understand the welding effects on the heat-affected zone (HAZ) of the welded joint. Although the API 5L X80MS (M – thermomechanical rolled; S – sour service) pipe has already been successfully developed and evaluated, the circumferential girth welding still requires study and development. The literature available about the weldability of this material is very limited. Most of the welding studies found are related to conventional non-sour API 5L X80 pipes [5–8] or API 5L X80QS (Q – quenched and tempered; S – sour service) seamless pipes [9,10].
Fault and fracture study by incorporating borehole image logs and supervised neural network applied to the 3D seismic attributes: a case study of pre-salt carbonate reservoir, Santos Basin, Brazil
Published in Petroleum Science and Technology, 2022
Amir Abbas Babasafari, Guilherme Furlan Chinelatto, Alexandre Campane Vidal
The Brazilian pre-salt carbonate rocks of the rift and post-rift stages in the Santos Basin were deposited during the Barremian and Aptian ages. These rocks are associated with regional uplift, erosion and unconformity events, and fault activation. During this period, grabens and horsts were formed via normal and strike-slip faults within the extensional tectonic setting. This process culminated in the distinct paleo-environmental depositional conditions resulting in a diversity of carbonate deposits, as observed in the Itapema and Barra Velha formations. These carbonate rocks exhibit a variety of pore types and a wide range of heterogeneity along with depositional and diagenetic features (Chinelatto et al. 2020).