DIKE F PUTRA

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Dike Putra is a seasonal Chief Reservoir Engineer over 20 years experiences worldwide. His expertise scope comprises Black oil and compositional simulation modeling, and several methodologies of EOR, such as WAG, Thermal, CO2, and Chemical, and also field development of oil and gas field, either Greenfield or Brownfield, as well as geomechanics as his update enhancement skills. Master graduated from NTNU Norway and the University of Manchester. Excellent in Strategic Management implementation, and certified by APEGA Canada as Professional Engineer (P.Eng) designation. Currently, lead R&D division of PT. Panji Laborta Chemindo and Rafflesia Energy Inc.

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Karl Stephen

Heriot-Watt University

Suman Paul

Presidency University, Bengaluru

Deepa Subramanian

Yale University

Julius U Akpabio

University of Uyo, Uyo, Nigeria

Mufazzal Kabuli

Australian College of Kuwait

Dahlia A . Al-Obaidi

University of Baghdad

Rotimi Oluwatosin

Covenant University Canaanland, Ota.

M. Al-marhoun

King Fahd University of Petroleum and Minerals

Cenk Temizel

University of Southern California

Rahul Ranjith

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Papers by DIKE F PUTRA

IPTC-18585-MS An Analysis of Multiplicative Schwarz Procedure in Coupling of Reservoir and Networks in Next-Generation Reservoir Simulators

by Cenk Temizel and DIKE F PUTRA

With the increasing use of reservoir simulation, not only in conventional reservoir modeling, but... more With the increasing use of reservoir simulation, not only in conventional reservoir modeling, but also in complex and large reservoirs, the need for faster and more robust modeling of reservoirs, along with the facilities and surface networks, has become crucial to meet the requirements of modeling either large or multiple sub-reservoirs with thousands of wells and surface networks, including pipelines and gathering centers, connected all the way to the separators. Next-generation reservoir simulators have begun replacing conventional reservoir simulators over the last decade in conjunction with the addition of more features that enable them to model different phenomena of reservoir fluid flow and recovery techniques, putting them at the forefront of reservoir simulation. While next-generation simulators offer more convenient solutions through surface-subsurface coupling and faster simulations that save time in decision-making processes in reservoir management, there are still some difficulties for the user, as well as in the development of these simulators from a computational point of view. The objective of this study is to outline the strengths and weaknesses along with the challenges in this process to serve as a guide for more efficient use. This study presents an analysis of an important component in the reservoir-network-coupling process in which the reservoir unknowns and network equations are solved iteratively. In the Schwarz procedure, the overlap region consists of reservoir cells included in the network set. An optimum solution for the number of cells extended into the network is important, because as the number of reservoir cells included in the network increases, the cost of the network to solve increases, which can become quite expensive, since bigger and more complex networks are needed to find the solution. This study highlights the effect of using different options for a better understanding of the important components of the coupling process; the results serve as a guide for a more efficient use of this procedure. Reservoir simulation involves several complex calculations to model the full-physics of the subsurface flow, as well as the well and surface facilities. It is not straightforward and easy to model and computationally evaluate the modeled phenomena. Discretizations and approximations contribute to error. Run time is another component that must be managed to find a balance between accuracy, precision, and time. Literature lacks practical examples of the Schwarz procedure, which is another important component

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An Analysis of Multiplicative Schwarz Procedure in Coupling of Reservoir and Networks in Next-Generation Reservoir Simulators

by Rahul Ranjith, Tanabordee Duangprasert, DIKE F PUTRA, Cenk Temizel, and Karthik Balaji

International Petroleum Technology Conference, 2016

Production Optimization under Injection of Biopolymer, Synthetic Polymer and Gels in a Heterogeneous Reservoir

by Rahul Ranjith, DIKE F PUTRA, Onur Susuz, Cenk Temizel, and Karthik Balaji

SPE Eastern Regional Meeting, 2016

Surface Web Balance Method: A Neural Network-Based Approach to Mitigate Subsidence in Diatomites Coupling Surface Deformation and Injection/Production Data

by Rahul Ranjith, DIKE F PUTRA, Cenk Temizel, Aditya Tiwari, and Karthik Balaji

SPE Annual Technical Conference and Exhibition, 2016

Integrated Workflow for Robust Reservoir Management through Production Optimization in Reservoirs with Geomechanics-Dependent Permeability

by DIKE F PUTRA, Sinem Aktas, and Aditya Tiwari

Offshore Technology Conference Asia, 2016

A Critical Investigation of Optimization of Steam-Assisted Gravity Drainage (SAGD) in Naturally-Fractured Heavy Oil Carbonate Reservoirs

by Cenk Temizel, DIKE F PUTRA, and Suryansh Purwar

Advancing technology in thermal recovery and declining conventional oil resources are leading to ... more Advancing technology in thermal recovery and declining conventional oil resources are leading to the increased application of thermal heavy oil recovery processes. Heavy oil resources in carbonate rock are estimated at 1.6 trillion bbl, one-third of which is in the Middle East, making it a crucial part of the global energy supply. A thorough understanding of reservoir properties (including but not limited to natural fracture systems, fluid saturation, permeability and rock matrix) is fundamental to optimizing recoveries with existing uncertainties, where efficient optimization through simulation can lead to the application of optimum operational decision parameters combined with improved understanding of the significance of such uncertainty parameters. Steam-assisted gravity drainage (SAGD) provides many advantages compared to conventional surface mining extraction techniques and alternate thermal recovery methods. These advantages include significantly greater per-well production rates, greater reservoir recoveries, reduced water treating costs, and dramatic reductions in steam-oil ratios (SORs). However, carbonate reservoirs exhibit varying properties in terms of porosity, permeability, and flow mechanisms. Many other engineering considerations exist for SAGD, including recovery rate, thermal efficiency, capability and economics of drilling horizontal well pairs, steam quality, steam injection rate, steam pressure, sand production, reservoir pressure maintenance, and water intrusion. In this study, such parameters are simulated and optimized by coupling a numerical reservoir simulator with commercial optimization software featuring exploratory, gradient, and direct methods. A dual permeability approach to modeling naturally fractured reservoirs is used. The results are discussed and the significance of both uncertainty and decision parameters is outlined in addition to the added benefits of optimized solutions using various optimization techniques. The results and observations show significant improvement using the optimum combination of decision parameters, such as steam injection rate, pressure, and temperature, to improve recoveries with a good understanding of the significance of uncertainty parameters, including rock and formation properties, in addition to overburden conditions that can affect the SAGD process. Reservoir management requires effective risk management where a sound understanding of uncertainties is fundamental to success. This study outlines all of these parameters in a comparative way, which can be useful in future industry applications. Modeling fractures in carbonates in heavy oil reservoirs is not an easy task because of the modeling and computational difficulties. It is important to have solid thorough examples, including building the model, setting up the optimization workflow of uncertainty, and outlining the results in a comparative manner to enhance understanding for more efficient reservoir management during SAGD processes.

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IPTC-18585-MS An Analysis of Multiplicative Schwarz Procedure in Coupling of Reservoir and Networks in Next-Generation Reservoir Simulators

by Cenk Temizel and DIKE F PUTRA

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An Analysis of Multiplicative Schwarz Procedure in Coupling of Reservoir and Networks in Next-Generation Reservoir Simulators

by Rahul Ranjith, Tanabordee Duangprasert, DIKE F PUTRA, Cenk Temizel, and Karthik Balaji

International Petroleum Technology Conference, 2016

Production Optimization under Injection of Biopolymer, Synthetic Polymer and Gels in a Heterogeneous Reservoir

by Rahul Ranjith, DIKE F PUTRA, Onur Susuz, Cenk Temizel, and Karthik Balaji

SPE Eastern Regional Meeting, 2016

Surface Web Balance Method: A Neural Network-Based Approach to Mitigate Subsidence in Diatomites Coupling Surface Deformation and Injection/Production Data

by Rahul Ranjith, DIKE F PUTRA, Cenk Temizel, Aditya Tiwari, and Karthik Balaji