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Collaborating Authors
Results
An Integrated Geomechanics and Corrosion Assessment Approach to Analyze Tubular Degradation in Brownfield X
Sajjad, Farasdaq Muchibbus (PT Pertamina Hulu Energi) | Wirawan, Alvin (PT Pertamina Hulu Energi) | Chandra, Steven (Institut Teknologi Bandung) | Ompusunggu, Janico Zaferson (PT Pertamina Hulu Energi) | Prawesti, Annisa (PT Pertamina Hulu Energi) | Suganda, Wingky (PT Pertamina Hulu Energi) | Muksin, M. Gemareksha (PT Pertamina Hulu Energi) | Amrizal, Amrizal (PT Pertamina Hulu Energi)
Abstract Tubular engineering design is essential for production operation, especially in the mature oil and gas fields. The complex interaction among oil, natural gas, and water, complemented with wax, scale, inorganic compound, and deformation brings complexity in analyzing tubular integrity. This challenging problem will be more severe if the wells are located in offshore environment, therefore finding the cause of tubing deterioration is a challenging. Field X, which has been in production for 30 years, cannot avoid the possibility of tubular thinning and deformation. The degradation is slowly developed until severe alterations are observed on the tubing body. The current state of the wells is complicated since the deformation inhibits the fluid flow and increases the risk of wellbore collapse and complications during sidetracking, infill drilling, workover, and other production enhancement measures. The risks can be harmful in the long run if not mitigated properly. The current condition encourages us to conduct more comprehensive study on tubular degradation. It is to model the multiple degradation mechanisms, such as corrosion, scaling, and subsidence, under the flowing formation fluid. The model is then coupled with reservoir simulation in order to provide a better outlook on tubular degradation. We used multiple case studies with actual field data to identify the dominant mechanism on tubular degradation. The case study cover various reservoir and fluid characteristics and also operations problems to develop general equation and matrix for risk analysis and field development considerations. We present the degree of tubular degradation and its effect to overall field performance and economics. Current field practices do not encourage a thorough tubular assessment during early life of the wells, which create complex problem at later stage. The study indicates that a proper planning and preventive action should be performed gradually before tubular degradation becomes severe. The paper presents a field experience-based model and guideline matrix that is useful in developing new areas from the perspective of well and facilities integrity, so that the degradation-related issues could be recognized earlier.
- Asia > Indonesia (0.29)
- Asia > Middle East (0.28)
- North America > United States > Texas > Coleman County (0.24)
Forced Oil-Water Emulsion to Tackle Flow Assurance Issues in Heavy Oil Reservoir
Sajjad, Farasdaq Muchibus (PT Pertamina Hulu Energi) | Nugroho, Wisnu Agus (PT Pertamina Hulu Energi) | Chandra, Steven (Institut Teknologi Bandung) | Panaiputra, Harris Grenaldi (PT Pertamina Hulu Energi) | Nurlita, Dian (PT Pertamina Hulu Energi) | Towidjojo, Reynaldo Billy (Institut Teknologi Bandung) | Rahmawati, Silvya Dewi (Institut Teknologi Bandung) | Vico, Hendro (PT Pertamina Hulu Energi) | Wirawan, Alvin (PT Pertamina Hulu Energi)
Abstract Flow assurance has been a major problem in the development of a heavy oil field. It is not common that this issue has a multiplier effect from reservoir up to processing facilities, reducing productivity and in turn, increasing financial burden. Many of oil and gas operators in Indonesia have spent a lot of capital to deal with managing complex reservoirs with severe flow assurance issues, namely high water cut, excessively viscous oil and its effect on fluid flow. Y Field has been produced for thirty years and currently produces 2800 BOPD with fluctuations in flow rate. This field is characterized by extreme oil viscosity, up to 4000 cP at surface condition, which leads to high backpressure while delivering fluid to pipeline system. This viscous oil creates unstable flow, causing unfavorable flow-pattern; slug flow to annular flow. As a result, the water and oil are not coherently arrived at the same time at receiving facilities, leading to highly frequent occurrence of oil-water slug phenomenon. Chemical injection efforts do not show significant impact toward the production, therefore an alternative approach is generated to address the production problem. A new approach is presented in this publication to reduce the occurrence of severe slugging phenomenon by performing water blending scheme during fluid transportation. The idea is based on a hypothesis that performing forced emulsion of brine and heavy oil promotes dispersion of oil into small droplets which can be carried out by injected water under relatively low velocity of fluid flow. This idea is quite interesting since it is simple to perform, by only directing produced water from water zones below hydrocarbon bearing zone or by reactivating high water cut wells to the pipeline system. In order to increase the efficiency of forced emulsion process, we approximated the minimum acceptable water cut to develop sufficient emulsion viscosity to prevent exceeding backpressure. Based on simulation using commercial software, the result shows that water cut should be maintained above 80%. A lower water cut will lead to high backpressure which will delay arrival time of oil for more than one day behind the water arrival. This result infers that one of the available solutions to handle severe slugging is by modifying water cut profile during hydrocarbon transportation. This approach gives a new insight into marginal field optimization.
- North America > United States (0.69)
- Asia > Indonesia (0.49)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Treatment (0.46)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Conformance improvement (1.00)
- Reservoir Description and Dynamics > Fluid Characterization > Phase behavior and PVT measurements (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
Numerical Modeling of Nanoparticles Transport in Porous Media for Optimisation in Well Stimulation and EOR Using Electromagnetic Heating
Santoso, R. K. (Institut Teknologi Bandung) | Rachmat, S.. (Institut Teknologi Bandung) | Putra, W. D. (Institut Teknologi Bandung) | Resha, A. H. (Institut Teknologi Bandung) | Hartowo, H.. (Institut Teknologi Bandung)
Abstract Electromagnetic heating has been recently introduced as an effective technology to enhance production of heavy and extra-heavy oil reservoir. Several investigations using metal oxide nanoparticles have successfully proven to increase the effectiveness of heating process. Nanoparticles act as thermal-conducting agent during the heating process. Thus, heat distribution along the reservoir strongly depends on the nanoparticles distribution (concentration profile along the reservoir). In this study, we develop a mathematical model to characterize the concentration distribution of nanoparticles along the reservoir during injection phase. The model is developed using material balance and fluid flow in porous media. Several empirical correlations are also adopted to describe the adsorption phenomenon during the nanoparticles flow in the reservoir. Using coreflood experiment data of iron oxide nanoparticles, the model is simulated and fitted to look for several constants and confirm the minimum error. From the simulation results, the model matched with tracer data and had small squared error with nanoparticles data.
- North America > United States (1.00)
- Asia (0.69)
- Research Report > Experimental Study (0.68)
- Research Report > New Finding (0.67)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
An Investigation of Fe2O3 Nanoparticles Diffusion into Oil for Heat Transfer Optimisation on Electromagnetic Heating for Well Stimulation and EOR
Santoso, R. K. (Institut Teknologi Bandung) | Rachmat, S.. (Institut Teknologi Bandung) | Resha, A. H. (Institut Teknologi Bandung) | Putra, W. D. (Institut Teknologi Bandung) | Hartowo, H.. (Institut Teknologi Bandung) | Setiawati, O.. (Institut Teknologi Bandung)
Abstract The use of iron oxide nanoparticles in electromagnetic heating application has been proven through several investigations to increase the electromagnetic absorption properties of reservoir, then, significantly increase the generated temperature. A factor that affects the temperature build-up is nanoparticles transport mechanism. When the nanoparticles carrier fluid is in contact with oil, it is possible for mass transfer to occur. Thus, nanoparticles can diffuse from its carrier fluid to oil in the reservoir. This mechanism is advantageous in increasing the oil temperature because it reduces the heat loss. In this study, we investigate the diffusion mechanism of iron oxide nanoparticles from brine to oil. We used 1% NaCl solution as the brine and nanoparticles carrier. The experiments are done with variation of the type of oil, nanoparticles concentration and sonication time. Heavy and asphaltic oil creates barrier for nanoparticles to diffuse, therefore, diffusion of nanoparticles from brine to oil is very small. Increase in nanoparticles concentration and sonication time provides more driving force for nanoparticles to move to oil. However, it is not always as ideal as those conditions, interaction among nanoparticles, such as aggregation creates various unpredictable results in the experiments.
- North America > United States (0.71)
- Asia (0.70)
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (0.53)
- Geology > Mineral > Oxide > Iron Oxide (0.46)