Success Story of Integrated Reservoir Characterization and Reservoir Management Approach to Deliver Infill Wells in the MTJDA Area, North Malay Basin

Reservoir Management Paradigm Shift Upon Successful Recent Drilling Well of Sungai Gelam Field, Jambi

10.29118/ipa21-e-44 ◽

2021 ◽

Author(s):

R. Rahadian

Keyword(s):

Reservoir Characterization ◽

Water Injection ◽

Reservoir Management ◽

Velocity Model ◽

Management Approach ◽

Field Development ◽

Well Location ◽

New Findings ◽

Infill Drilling ◽

Water Cut

Sungai Gelam structure is one of the backbone brownfield structures supporting Jambi field oil productions. Geologically, Sungai Gelam is highly related to structural-trap type which commonly occur in Air Benakat Formation, as main hydrocarbon producer. There are total 29 wells in Sungai Gelam penetrate the Air Benakat Formation, some extend through the Talang Akar Formation. Re-evaluation of the last two years (S-25 and S-26) of infill drilling program indicate unsatisfactory production results. The latest two wells which have been drilled in 2018 have been used to update velocity model, facies model and the reservoir simulation. Considering tremendous depth uncertainty on the western part of the field, several new infill well locations have now been planned to recover bypassed oil within the existing wells, to acquire new velocity data and to be water injection conversion-ready location for the productive reservoirs. The overall reservoir management approach has been thought to be the most benign option for the field. Well S-27 has been approved in 2019 as one of the best infill locations. The well location bears the lowest risks and produces a naturally flowing 286 BOPD far beyond the predicted oil target. It also yields a 2040 psia virgin formation pressure oil column from new N1 sand productive target which have not fully developed by the existing wells. The discovery leads to a speedy work over program at the existing nearby well, S-23, and produces 212 BOPD with 0% water cut. Two infill wells acceleration have been proposed for year 2020. The field’s reservoir characterization study has been yet again recycled by the new target oil. The field has now been under drastic redevelopment plan with more detailed reservoir flow unit modeling, new data acquisition, PSDM seismic reprocessing, new infill wells and step-out wells targeting deeper reservoirs. Sungai Gelam field development shows strong fundamental yet versatile field reservoir management rendering to real-time drilling data. New findings have been seamlessly adjusted in the framework and acted upon accordingly. Production of S-27 and S-23 well then accelerate additional two drilling wells which drilled in 2020.

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Modern Reservoir Management Approach in Enhanced Oil Recovery Projects

10.29118/ipa.996.487 ◽

2018 ◽

Author(s):

Dedy Kristanto

Keyword(s):

Enhanced Oil Recovery ◽

Oil Recovery ◽

Reservoir Management ◽

Management Approach

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Digital Workflow to Enhance Reservoir Management Strategies for A Complex Oil Field Through Real Time and Advanced Engineering Monitoring Solution

10.2118/200932-ms ◽

2021 ◽

Author(s):

Julieta Alvarez ◽

Oswaldo Espinola ◽

Luis Rodrigo Diaz ◽

Lilith Cruces

Keyword(s):

Real Time ◽

Reservoir Characterization ◽

Management Strategies ◽

Reservoir Management ◽

Gas Production ◽

Oil Field ◽

Oil Reservoirs ◽

Production Operation ◽

Digital Workflow ◽

Operational Decisions

Abstract Increase recovery from mature oil reservoirs requires the definition of enhanced reservoir management strategies, involving the implementation of advanced methodologies and technologies in the field's operation. This paper presents a digital workflow enabling the integration of commonly isolated elements such as: gauges, flowmeters, inflow control devices; analysis methods and data, used to improve scientific understanding of subsurface flow dynamics and determine improved operational decisions that support field's reservoir management strategy. It also supports evaluation of reservoir extent, hydraulic communication, artificial lift impact in the near-wellbore zone and reservoir response to injected fluids and coning phenomenon. This latest is used as an example to demonstrate the applicability of this workflow to improve and support operational decisions, minimizing water and gas production due to coning, that usually results in increasing production operation costs and it has a direct impact decreasing reservoir energy in mature saturated oil reservoirs. This innovative workflow consists on the continuous interpretation of data from downhole gauges, referred in this paper as data-driven; as well as analytical and numerical simulation methodologies using real-time raw data as an input, referred in this paper as model-driven, not commonly used to analyze near wellbore subsurface phenomena like coning and its impact in surface operation. The resulting analyses are displayed through an extensive visualization tool that provides instant insight to reservoir characterization and productivity groups, improving well and reservoir performance prediction capabilities for complex reservoirs such as mature saturated reservoirs with an associated aquifer, where undesired water and gas production is a continuous challenge that incorporates unexpected operational expenses.

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