Investigation of EOR methods for Nagani oil field
Author
Vakova, Petya
Term
4. term
Education
Publication year
2014
Submitted on
2014-06-16
Abstract
Formålet med projektet var at vurdere og anvende en metode til forbedret olieindvinding (EOR) i Nagani-olieområdet. Først blev reservoirets egenskaber sammenholdt med etablerede screeningskriterier for at finde en passende EOR-metode. Ud fra denne vurdering pegede resultaterne på polymerforstærket vandinjektion (polymer flooding) som det mest egnede valg. I denne metode tilsættes små mængder polymer til injektionsvandet for at øge dets viskositet og dermed forbedre fortrængningen af olie. Der blev udviklet en analytisk tilgang til at forudsige reservoirets ydelse, først for traditionel vandinjektion og derefter for polymerforstærket vandinjektion. Dette krævede en grundig gennemgang af empiriske data og beregninger for at estimere den ekstra olieudvinding, polymeren kan give. I den sidste del blev data og resultater for Nagani samlet og sammenlignet for to cases: Case 1 med vandinjektion og Case 2 med polymerforstærket vandinjektion. Sammenligningen blev gennemført med Eclipse Black Oil simulator 2008.1. For bedre at tilpasse den viskositet, der anvendes i modellen, og reducere usikkerheden om oliens reelle viskositet i reservoiret (in situ), blev der udført to laboratorieundersøgelser. Formålet var at observere, hvordan viskositeten ændrer sig med temperaturen under isobare (konstante tryk) forhold. Samlet set understøtter arbejdet, at polymerforstærket vandinjektion er en velegnet EOR-metode for Nagani.
This project aimed to evaluate and apply an enhanced oil recovery (EOR) method in the Nagani oil field. First, the reservoir’s properties were compared against established screening criteria to identify a suitable EOR approach. Based on this assessment, polymer-augmented water flooding (polymer flooding) was selected as the most appropriate option. In this method, small amounts of polymer are added to the injected water to increase its viscosity and improve oil displacement. An analytical approach was developed to estimate reservoir performance, initially for conventional water flooding and then for polymer-augmented water flooding. This required a thorough review of empirical data and calculations to evaluate the incremental oil recovery attributable to the polymer. The final part integrated data and results for Nagani and compared two cases: Case 1 with water flooding and Case 2 with polymer-augmented water flooding, using the Eclipse Black Oil simulator 2008.1. To better match the viscosity used in the model and reduce uncertainty about the oil’s in-situ viscosity, two laboratory studies were conducted to observe how viscosity changes with temperature under isobaric (constant-pressure) conditions. Overall, the work supports polymer-augmented water flooding as a suitable EOR method for Nagani.
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