CCGS Opportunities in the Santos Basin Pre-Salt Development

Almeida, Alberto Francisco Ribeiro de; Lima, Saulo; Rocha, Paulo Alexandre Costa; Andrade, Ana Maria de; Branco, Celso Cesar M.; Pinto, Antonio Capeleiro

doi:10.2523/126566-ms

Cited by 12 publications

(1 citation statement)

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“…The strategy of CO 2 reinjection has been chosen in different projects for the pre-salt development (Almeida et al, 2010). Besides the commitment of avoiding CO 2 emissions to the atmosphere, it can be used as an EOR method, also in connection with the WAG technique, which can improve reservoir sweep and displacement efficiency.…”

Section: Phase Behavior and Pvt Propertiesmentioning

confidence: 99%

Numerical Simulations of High CO2 Content Flows in Production Wells, Flowlines and Risers

Carneiro

Pasqualette

Reyes

et al. 2015

Day 2 Wed, October 28, 2015

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There are several challenges associated to the pre-salt development at the Santos basin, such as long distances from the coast, low temperature reservoirs, high pressures, high water depth, among others. Additional aspects contributing to the complex production scenario are related to fluid characteristics and flow assurance. In particular, the high CO 2 content in the dissolved gas is an important characteristic that should be also analyzed, because CO 2 is not only a heavy component, when compared to lighter components present in the gas phase, but has also a high Joule-Thomson coefficient. This affects pressure drop and specially the mixture cooling behavior during decompression. The cooling effect is expected to be strong at high production rates. Thus, the objective of the present work is to evaluate these effects under present and future production scenarios, taking into account increasing CO 2 contents due to re-injection strategies.Two different field configurations were investigated and a variety of operating conditions was used, along with real and model fluids ranging from 5% to 50% CO 2 content (molar basis). PVT data for the model fluids with high CO 2 content were generated by a simulated swelling test with CO 2 of an existing mixture with lower CO 2 content. A parametric study was carried out aiming at investigating primarily the total pressure and temperature drop in the pipeline when the total CO 2 content of the mixture is increased. Furthermore, variation of the fluid properties along the well, flowline and riser was evaluated. Results are also discussed in view of the impact of increasing CO 2 contents and the challenges experienced during simulation of such flows.

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Section: Phase Behavior and Pvt Propertiesmentioning

confidence: 99%

Numerical Simulations of High CO2 Content Flows in Production Wells, Flowlines and Risers

Carneiro

Pasqualette

Reyes

et al. 2015

Day 2 Wed, October 28, 2015

View full text Add to dashboard Cite

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Assessment of continuous and alternating CO2 injection under Brazilian-pre-salt-like conditions

Lima¹,

Cunha²,

Santos³

et al. 2020

J Petrol Explor Prod Technol

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Carbonate rocks have become very important in Brazil with pre-salt reservoir discoveries in Santos and Campos Basins. Since then, great efforts in research and technology have been made to characterize and develop these reservoirs. In this sense, outcrop analogue studies have become a powerful tool for helping the recognition of geological heterogeneities responsible for controlling the fluid flow in hydrocarbon reservoirs. Besides that, pre-salt oil recovery is associated with high carbon dioxide (CO 2) production, and due environmental issues, it is required a sustainable destination for this contaminant. CO 2 injection in the reservoir, either pure or mixed to the produced gas stream, could be a good manner to deal with this undesirable component and increase the oil recovery. This work uses outcrop analogue characterization to understand how carbonate reservoir characteristics impact the selection of the best recovery strategy under Brazilian-pre-salt-like conditions. Numerical simulation models were run using the flow simulator TEMPEST MORE (version 7.1) with isothermal compositional modeling. The oil recovery process was modeled by continuous and alternating injection of CO 2 and water. The recovered oil fractions for the simulation case with water alternating CO 2 injection were higher than with the use of continuous injection of CO 2 or water.

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Development of the Brazilian Pre-Salt Fields – When to Pay for Information and When to Pay for Flexibility

Moczydlower

Salomao

Branco

et al. 2012

SPE Latin America and Caribbean Petroleum Engineering Conference

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The Santos Basin Pre-Salt Cluster (SBPSC), Offshore Southeast Brazil, is a unique scenario, posing great development challenges. The microbial carbonate reservoir is unusual regarding its origin and petrophysical properties; the fluids have a variable CO2 content; the few analogue reservoirs around the world do not compare in terms of volumes, water depth and distance to the coast; and there are also flow assurance issues. Considering the importance of these reserves for the Brazilian economy and the opportunity to accelerate cash flow, Petrobras and its partners have opted for a fast track development, including extended well tests (EWTs) and production pilots. The current Petrobras Business Plan (2011–15) foresees that the SBPSC areas alone will produce over 500,000 boe/d in 2015 and over 1,100,000 boe/d in 2020. These numbers refer only to Petrobras share and do not include the transfer of rights with economic compensation from the Brazilian government to Petrobras. Therefore, the initial development phase will have to cope with several uncertainties, mainly the subsurface ones. Some of the most relevant are the quality and the heterogeneity degree of each reservoir zone; the compositional grading of the fluids; the performance of different EOR methods; and the presence of fractures affecting the flow. How to specify and anticipate the acquisition of expensive equipment, such as FPSOs and subsea devices, with uncertainties to be clarified? When is it worth to invest in more data acquisition, such as EWTs, core and fluid sampling, extensive lab analysis or even more appraisal wells? The timing and the uncertainty reduction foreseen for each initiative must be taken into account. On the other hand, when is it better to pay for extra flexibilities, accepting the inevitable CAPEX increase? Some examples would be: smart completions and possibility to inject different chemical products in the wells; gas and water separated lines for each satellite injector; flexible subsea layout, allowing multiples strategies and the addition of more wells; FPSO plants designed to inject desulphated water, or to export, import or reinject the gas, and also to separate variable CO2 contents in the produced fluids. This paper aims to discuss the influence of the main subsurface uncertainties in the selection of alternatives to develop the giant fields in the SBPSC, in a fast track way.

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CCGS Opportunities in the Santos Basin Pre-Salt Development

Cited by 12 publications

References 0 publications

Numerical Simulations of High CO2 Content Flows in Production Wells, Flowlines and Risers

Numerical Simulations of High CO2 Content Flows in Production Wells, Flowlines and Risers

Assessment of continuous and alternating CO2 injection under Brazilian-pre-salt-like conditions

Development of the Brazilian Pre-Salt Fields – When to Pay for Information and When to Pay for Flexibility

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