Heavy-Oil Papa-Terra Project Uses Innovative Solutions in Deep Water
- Adam Wilson (JPT Special Publications Editor)
- Document ID
- Society of Petroleum Engineers
- Journal of Petroleum Technology
- Publication Date
- May 2014
- Document Type
- Journal Paper
- 102 - 105
- 2014. Offshore Technology Conference
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- 188 since 2007
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This article, written by Special Publications Editor Adam Wilson, contains highlights of paper OTC 24504, "Papa-Terra Project: Use of Innovative Solutions for Heavy Oil in Deep Water," by D.S. Condessa, G.S. Damno, S.C. Vieira, and W.P. Goncalves, Petrobras, prepared for the 2013 Offshore Technology Conference Brasil, Rio de Janeiro, Brazil, 29-31 October. The paper has not been peer reviewed. Copyright 2013 Offshore Technology Conference. Reproduced by permission.
The Papa-Terra field in the Campos basin in Brazil is identified as having an oil interval of 14.6°API in turbidite sandstones. Because of the high-viscosity oil and low-API grade, innovative solutions and technological advances were incorporated into the project. The development uses an integrated production system consisting of a floating production, storage, and offloading (FPSO) vehicle connected to a tension-leg wellhead platform (TLWP) and dry completion wells. This allows the production of ultraheavy oil in deep water and enables rapid intervention for maintenance of electric submersible pumps (ESP).
Because of the properties of the oil from the Papa-Terra field (high viscosity at low temperatures and low gas/oil ratio), the whole production development concept of the field was driven by artificial lift and flow-assurance requirements.
This led Petrobras to a field-development concept that uses two production units, an FPSO (P-63) and a TLWP (P-61), 350 m apart.
The P-61 platform will be connected with 13 dry-completion wells, and all production will be exported to P-63, where it will be joined with the production from five wet-completion wells to be processed. The TLWP will not have a process plant to separate oil, gas, and water and will transfer all produced fluids to FPSO P-63 through multiphase pumps.
As a secondary recovery method, 10 injector wells will be placed at the reservoir extremities to maintain pressure in the reservoir (Fig. 1).
As a consequence of this development, and mainly because of the oil properties, the items that needed to be developed to make the project technically viable and economical attractive are
- High-power ESP
- TLWP as a production unit
- Conductor-driven installation
- Thermal-insulated TLWP risers
- Tender-assisted drilling (TAD) unit
- Fluid-transfer lines at midwater
- Electrical-heated flexible pipe
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