Abstract

Papa-Terra field is operated by Petrobras in Partnership with Chevron, and located in the Campos Basin, Brazil, 110 kilometers from the coast.

Discovered on June 2003, it could be identified an oil interval of 14.6°API in Turbidities Sandstones. The field extends over an area of 183 square kilometers, in water depth that varies from 400 to 1400 meters.

Due to the high viscosity oil and low API grade, creative and innovative solutions with technological advances were incorporated to the project.

The development of the field considers an integrated production system consisting of an FPSO interconnected to a TLWP, with dry completion wells. By this way the production of ultra-heavy oil in deep water becomes viable, opening a new frontier for the production of high viscosity oil at reservoir and enabling rapid intervention in the wells for the ESP (Electric Submersible Pumps) maintenance.

There are 13 dry completion horizontal production wells interconnected to the TLWP, added to 5 productions and 10 water satellites injection wells connected to the FPSO. The wells drilling from the TLWP will be supported by a TAD rig (Tender Assisted Drilling). This allows the drilling rig to be temporarily installed upon the TLWP, which enabled significant optimization of the project by the size and cost of TLWP reduction.

The wet completion production wells will be interconnected to the FPSO using flexible pipeline with electrical heating and temperature monitoring system, to mitigate the production losses risk during production restart.

The Subsea injection wells will be equipped with Christmas Trees in Piggyback. To maximize the recovery, with the maintenance of high water injection flow rate, it is considered a pilot system of polymers injection in one of the water injection wells in order to elevate the water viscosity.

The production from the TWLP will be transferred by multiphase flow pumps to the FPSO through Fluid Transfer Lines (FTL) in a mid-water depth configuration. It will be the first use of this kind of solution in Brazilian waters and this configuration will avoid the cooling of the oil as it can occurs on conventional solutions when the lines are installed on the sea floor at deep water.

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