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Collaborating Authors
Praditya, Yusuf Alfyan
Opportunity vs Risk : Connected Volume Uncertainty in Highly-Faulted Reservoirs - Case Study and Lesson Learn
Praditya, Yusuf Alfyan (Premier Oil Indonesia – A Harbour Energy Company) | Susanto, Chrisnadi (Premier Oil Indonesia – A Harbour Energy Company) | Patria, Masio (Premier Oil Indonesia – A Harbour Energy Company) | Wibowo, Andi A. (Premier Oil Indonesia – A Harbour Energy Company) | Medianestrian, _ (Premier Oil Indonesia – A Harbour Energy Company) | Budiyono, _ (Premier Oil Indonesia – A Harbour Energy Company)
Abstract Subsurface uncertainty will always be part of the field development. Moreover, the existence of multiple faults that divides reservoirs into segments create more challenges and risks in understanding the field performance. In the other hand, this compartmentalized reservoirs typically also offer promising opportunities for undrained or virgin pressure reservoir development which can provide significant added value especially for mature assets. This paper presents valuable case study and lesson learn from Premier Oil Indonesia in modelling and estimating optimization opportunities in highly faulted reservoirs at Garuda Field located in Natuna Sea offshore. Several integrated studies that involved seismic reprocessing, static modelling, fault seal analysis, P/Z Analysis and MatBal simulation were done and lead to identification of several promising opportunities to produce the suspected undrained / high pressure reservoir compartments. However, uncertainty and risk will remain lay underground unless the opportunity is accessed or drilled. Two initial opportunities were drilled and workovered in 2021 that unfortunately had depleted pressure outcome – not align with initial expectation. Case study presented in this paper provide valuable insights and lesson learns in developing compartmentalized reservoirs. Especially when having infill well optimization programs among severely depleted neighbor sands. Despite alignments of several analysis, huge uncertainties are always involved when dealing this type of reservoirs, unless the well is drilled to provide some answers.
- Africa > Nigeria (0.46)
- Asia > Indonesia (0.34)
- North America > United States > Texas (0.28)
- Geology > Structural Geology > Fault (1.00)
- Geology > Structural Geology > Tectonics (0.68)
- Geology > Sedimentary Geology > Depositional Environment (0.68)
- (2 more...)
- Geophysics > Borehole Geophysics (0.88)
- Geophysics > Seismic Surveying > Seismic Processing (0.34)
Systematic Approach in Extending Liquid Loaded Offshore Gas Wells Production in Natuna Sea with Partial and Full Wellbore Water Shut Off: Case Study and Method Selection
Praditya, Yusuf Alfyan (Premier Oil Indonesia) | Satiawarman, Anugerah (Premier Oil Indonesia) | Nurrahman, Fahmi (Premier Oil Indonesia) | Medianestrian, Medianestrian (Premier Oil Indonesia) | Rochaendy, Risnawan (Premier Oil Indonesia)
Abstract Wells which produce dry gas reservoirs usually have low bottomhole pressure. But in many instance liquid is associated with the produced gas, it can come from the liquid in reservoir or condensed production liquid. When more liquid is introduced into the wellbore, the pressure gradient along the wellbore is higher. The increased liquid fraction creates higher backpressure on the reservoir delivering gas. In high pressure gas reservoir the presence of liquid can occur in several degree of bubble and slug flow; in depleted gas reservoir the liquid can kill the well as the gas does not have enough transport energy to lift the liquid. At the point when the gas velocity is insufficient to carry out liquid, liquid will start to drop and accumulate in the bottomhole creating a restriction on the gas flow path, the phenomena is called liquid loading. This paper presents success case studies from Premier Oil Indonesia in handling and reactivating four liquid loaded gas wells in Natuna Sea offshore operation. Wellbore configuration and facility limitations in offshore operation (e.g. maximum deck load capacity, water handling capacity and crane capacity) create more complexity of the method selection in comparison to onshore operation. There are many gas well deliquification methods available in the industry, but not in instance that each method is appropriate for all conditions. The case studies presented in this paper provide description of how Premier Oil Indonesia screened several available gas well deliquification methods in the industry and came up with the water shut off proposal as the best and most proper method for its wells. The understanding of liquid loading indication, liquid source identification and operational details of gas well deliquification methods are the most important factors to determine the most effective and cost efficient method to handle liquid loaded wells. This paper also presents a general guideline in selecting the best gas well deliquification method for some specific cases under several operational conditions for onshore and offshore operations.
- Asia > Indonesia (0.88)
- North America > United States > Texas (0.28)
- Asia > India > Andhra Pradesh > Bay of Bengal > Krishna-Godavari Basin > Block KGD6 > G-1 Well (0.99)
- Asia > Middle East > Iran > Arabian Gulf > Arabian Basin > Arabian Gulf Basin > G 3 Field (0.91)