TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe 2003 Brazilian deepwater drilling record (4 th in the world) was achieved with a slender well in a 2887-meter water depth in Campos Basin (block BMC-10), Rio de Janeiro. Uncommon to the drilling practices throughout the world and, particularly, in the Brazilian coast, the well was safely drilled with a surface blowout preventer system (SBOP). Beyond the importance of a world record class, the result points out to an important paradigm shift in the current technical culture throughout the country, considering safety (human, environmental and material), economical and regulatory issues which surrounds such decision taking task. This work presents two discussions: the first one concerns the technical issues considering well control operations performed on the drilled well and on a hypothetical conventional well that could also be drilled under the same conditions. This discussion involves the calculation of pressures at the choke, at the casing and liner shoes, pit gain and produced gas rates at the surface using the driller's method. The results were obtained with an existing well control simulator for deep and ultradeep water drilling. The second discussion concerns important aspects of the surface BOP technology mainly related to well control. Thus, the main objective of the present work is to bring to light a broad discussion regarding the potential application of the SBOP concept to explore and develop deep and ultradeepwater reserves in Brazil, with emphasis on well control.
The 2003 Brazilian deepwater drilling record (4th in the world) was achieved with a slender well in a 2887-meter water depth in Campos Basin (block BMC-10), Rio de Janeiro.Uncommon to the drilling practices throughout the world and, particularly, in the Brazilian coast, the well was safely drilled with a surface blowout preventer system (SBOP). Beyond the importance of a world record class, the result points out to an important paradigm shift in the current technical culture throughout the country, considering safety (human, environmental and material), economical and regulatory issues which surrounds such decision taking task. This work presents two discussions: the first one concerns the technical issues considering well control operations performed on the drilled well and on a hypothetical conventional well that could also be drilled under the same conditions. This discussion involves the calculation of pressures at the choke, at the casing and liner shoes, pit gain and produced gas rates at the surface using the driller's method.The results were obtained with an existing well control simulator for deep and ultradeep water drilling. The second discussion concerns important aspects of the surface BOP technology mainly related to well control.Thus, the main objective of the present work is to bring to light a broad discussion regarding the potential application of the SBOP concept to explore and develop deep and ultradeep-water reserves in Brazil, with emphasis on well control. Introduction For the first time in the world, a combination of surface BOP (SBOP) and a dynamically positioned semi-submersible drilling rig were used1 (up to now, 4 wells were drilled in Brazil and Egypt). The SBOP system included a surface mounted BOP, a 13 3/8" high pressure casing riser, a seabed shut-off and disconnect system (SDS), and control systems for these components.[2] The SBOP system has come out to make it viable to apply lower generation drilling rigs for ultradeep waters. Associated benefits can also be observed in reduced environmental damage due to the lower volumes of drilling fluid and additives, compared to the subsea BOP system. The most important part of this work presents a comparison of a gas kick circulation using the driller´s method between the 2887-meter water depth well drilled with a SBOP and a DP vessel and a hypothetical well drilled under the same condition, but applying a subsea BOP.The text was organized in the following topics:Well schematic and scenario - describing the depths, diameters, wellbore configuration and operational parameters of each scenario;Well control simulation results - showing the choke and casing pressures, as well as pit gain and gas flow rate out of the well as a function of displacement time, for both systems;Discussion on the utilization of surface BOP in deep and ultradeep waters. Well Schematics and Well Scenario Fig. 1 shows the wellbore configurations for the two scenarios investigated in this paper.On the left, it is shown the conventional situation where an 18 3/4" subsea BOP weighting 300ton is placed on the seabed and a 21" marine riser is attached to its top.On the right, a surface BOP situation is displayed.In this case, a BOP weighting 40ton is placed on the top of 13 3/8" high-pressure casing riser.The bottom end of the casing riser is connected to the subsea disconnection system (SDS), which is used in case of an emergency disconnection. Fig. 2 and Fig. 3 show, respectively, the casing design configurations for subsea and surface situations.The figures display the casing shoe setting depths and the total vertical depth (TVD) for both situations. Notice that a 9 5/8" liner is set on the 13 3/8" casing string and that there is an 8 ½" open hole below the 9 5/8" casing shoe in both situations. Other dimensions are presented as follows:Drillpipe: 5" OD X 4,276"IDDrillcollars: 500m of 6.5" OD X 2.5"IDChoke Line: 3"IDCasing Riser: 13 3/8"IDConventional Riser: 21"
Este trabalho não poderia ser terminado sem a ajuda de diversas pessoas e instituições às quais presto minha homenagem: À minha família, pelo apoio e compreensão durante todas as etapas deste trabalho. Ao meu orientador Paulo Roberto Ribeiro, pelo estímulo constante, acessibilidade, paciência e interesse pela execução do trabalho. Aos meus amigos do LEP Eduardo, Evilene e Nilo pela amizade, companheirismo e pelas sugestões e discussões durante a elaboração deste trabalho. Aos meus colegas de mestrado, que partilharam vários momentos de estudo, mas também momentos de lazer. Em especial Débora, Mauricio, Suzana e Juan. À Unicamp, pela infra-estrutura disponibilizada. À Agência Nacional do Petróleo pela bolsa de estudos concedida através do programa PRHANP-15. A todos os professores do Departamento de Engenharia de Petróleo que ajudaram, direta ou indiretamente, na realização deste trabalho. E aos professores Maria Cristina Cunha, Felipe Moura e Otto Santos pelas contribuições feitas durante a realização do trabalho. v A todos os amigos e companheiros do
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