Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022最新文献

{"title":"Palinspastic Reconstruction of X Block, Anggursi Sub-Basin","authors":"F. Yunus","doi":"10.29118/ipa22-sg-135","DOIUrl":"https://doi.org/10.29118/ipa22-sg-135","url":null,"abstract":"North Anggursi Sub-basin is one of the sub-basins in the North West Java Basin, located on northern of North West Java Basin. North Anggursi Sub-basin regionally was a sinistral pull-apart basin with northeast-southwest orientation which the direction of the extension was east west at Eocene. This subbasin is a back-arc basin during the Eocene to Oligocene. The dynamics of the North Anggursi Sub-basin were analysed using the palinspastic reconstruction method using 2D seismic lines which have east-west direction and biostratigraphy data. This analysis was carried out to determine the tectonic evolution to sub-basin tectonostratigraphy. Based on the results of subsurface mapping, the dominant type of geological structure in the study area is normal fault with NW-SE orientation. There was one unconformity phase during the Eocene. The forming of the North Anggursi Sub-basin began with the formation of Pre-Tertiary basement rock with an average rift of 6%. At Eocene began the syn-rift tectonic event with an average rift of 3%. After Eocene I, there was the deposition of Eocene II units which had compression with an average compression rate of 7% and then eroded. Syn-rift events began to end in the Oligocene with an average rift of 2%. Early Miocene began the post-rift phase with an average of rift of 1%. In Middle Miocene, there was an rift with an average of 1% and ended with Late Miocene by 0%. The intensity of rifting was very high during the Eocene, resulting in horst and half-graben morphology. The dynamics of the North Anggursi Sub-basin started from the Eocene to recent with three tectonic phases, they were the pre-rift that occurred during the Pre-Tertiary with the type of poly history basin of Continental Interior Sag (CIS), the syn-rift that occurred in the Eocene-Oligocene with the type of poly history basin of Continental Interior Fracture (CIF), and the post-rift the occurred in the Early Miocene-Late Miocene with the type of poly history basin of Continental Interior Sag (CIS).","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"102 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133713884","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Clastic Plays in The North East Natuna Basin","authors":"D. Mulyono","doi":"10.29118/ipa22-g-237","DOIUrl":"https://doi.org/10.29118/ipa22-g-237","url":null,"abstract":"The East Natuna Basin comprises several sub-basinal areas which formed during the Tertiary as a result of extension relating to the opening of the South China Sea during the Oligocene and Early Miocene. Several small Oligocene half-grabens occur in the northern part of the area close to where the Tuna Block is located. They have a NE-SW trend and the sediments are relatively uniform in thickness, less than 2,600 ft thick, with regional thickness growth to the east towards the basin center. However in the Lower Miocene a more pronounced extensional episode enlarged the existing half grabens and generated large growth fault related sediment packages consisting predominantly of clastic sequences. Marine conditions in the Mid Miocene gave rise to carbonate development which continued to the latest Miocene with some very large reef related carbonate build-ups observed on seismic. In Late Miocene this area underwent further deformation caused by right lateral transtension which produced numerous NE-SW normal faults. This was then followed by a period of quiescence and deposition of the overlying Pliocene Muda Formation marine shales and clastics. The tectonically controlled, locally thick sequences of the Oligocene and Lower Miocene sediments indicate good potential for source and reservoir/seal pair rocks. Exploration in the East Natuna Basin began in the 1970’s, mainly targeting the Terumbu Formation carbonate buildups, which were easily mapped on the available 2D seismic data. Some discoveries were made and the most significant of which was the supergiant D Alpha gas field discovery by AGIP in 1973 containing over 220 TCF including +/- 71% CO2. However, the underlying clastics were not well imaged by the 2D seismic data and many of the wells drilled were not optimally located for testing the underlying Arang and Gabus clastic sections. The discovery of hydrocarbons in the Gabus and Lower Terumbu clastics in the Kuda Laut-1 and Singa Laut-1 wells by Premier Oil in 2014 confirmed the exploration potential of these intervals. The discoveries now known as the Tuna Field were appraised by two additional wells in Q3-Q4 2021 confirming the presence of rich wet gas with a high condensate yield, but also encountering oil rims, to the previously discovered gas columns. The main reservoirs are Lower Terumbu shallow marine bioturbated shaly sandstones in the Kuda Laut hanging wall structure and Gabus fluvial channel sandstones in the Singa Laut footwall structure. These two reservoirs exhibit very different properties as indicated by conventional cores, extensive wireline data and the DST’s. Post well analysis is ongoing to further characterize these reservoirs and the fluids contained, the results of which will be critical for the commercial development of the Tuna field.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"20 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114510029","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Leading Edge of Well Abandonment and Workover Method Revolution for Sidetrack Drilling Preparation in Mahakam","authors":"G.A. Yandra W.","doi":"10.29118/ipa22-e-127","DOIUrl":"https://doi.org/10.29118/ipa22-e-127","url":null,"abstract":"Mahakam is an oil and gas field concession area managed by Pertamina Hulu Mahakam which has production for more than 50 years and has been classified as a brownfield because of the marginal reserved and declining production profile. In order to increase the economic value of the drilling process, sidetrack drilling has been introduced into Mahakam area to utilize non-producing well slot in the existing platform instead of building a new one. To carry out sidetrack drilling, the well abandonment and workover operation are done to prepare the old well slots. Revolution of method is initiated to conquer challenges to the more economical operation. Use of rigless unit using hydraulic workover unit and well intervention remote unit, plug and cut wireline technology, cement plug through existing tubing completion, cut and pull tubing / casing using fishing tool, improve well integrity by cementing through annulus casing, wireline gauge ring for checking casing clearance and other initiatives have been introduced to ensure the success of the sidetrack drilling preparation operation. The positive impact of the method is shown by the last milestone on the well abandonment and workover operation delivery within 3.5 days using rigless unit. It breaks the fastest record in Offshore Mahakam Field operation with 90% efficiency in well duration and cost. This achievement has become the leading edge innovation which brings significant economic value for the future development in Mahakam.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"3 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114192485","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Artificial Intelligence (AI) Based Personnel Protective Equipment (PPE) Monitoring – Case Study in Rokan Drilling Operation","authors":"F. F. Rizki","doi":"10.29118/ipa22-o-131","DOIUrl":"https://doi.org/10.29118/ipa22-o-131","url":null,"abstract":"Automatic Personal Protective Equipment (PPE) Monitoring System is a term for an image processing method which is used to identify compliance to PPE utilization practices by personnel on the field. The vast diversity and assortment of PPEs across companies make it quite challenging to take existing limited public dataset models from other companies and apply them directly to specific companies such as Pertamina Hulu Rokan. As a state-owned company that operates one of the largest fields in Indonesia with an extensive drilling program, Pertamina Hulu Rokan decided to use an Automatic PPE monitoring system with online Closed-Circuit Television (CCTV) units to enable recognition of PPE objects in drilling operations by the implementation of Artificial Intelligence. As a first step towards building this system, we proposed to build PPE datasets from various Rig areas and in different light conditions. The next step was to use deep learning technology such as Yolov4 and train the model using the PPE datasets to localize PPE objects used by personnel such as gloves, gloves-off, helmets, helmets-off, shoes, shoes-off, masks, masks-off, glasses, glasses-off. Our Preliminary results indicate that our method has been useful to identify compliance of PPE usage during operation work and to minimize the safety risk exposure of our personnel.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"97 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124796427","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Sensitivity Analysis on Oil Recovery Improvement Through Application of Fracture-Assisted Steamflood","authors":"S. Josefin","doi":"10.29118/ipa22-se-110","DOIUrl":"https://doi.org/10.29118/ipa22-se-110","url":null,"abstract":"The most common recovery method for heavy oil reservoirs is steam injection, which is one of the most effective thermal recovery processes. However, the application of steam injection comes with many challenges, for instance unexpected faults, heat transfer efficiency, and less exposure between oil and steam. The effectiveness of steam injection decreases with the lower exposure of oil to steam. One way to tackle this problem is by applying hydraulic fracturing to increase the surface area of oil to steam. This fracture-assisted steam flooding process is a rising new technique in which a path is created between injection wells and production wells. In this paper, the effects of a hydraulically fractured reservoir in the steam injection process are simulated and evaluated using a commercial simulator. The focus of this research is to find the best fracture properties by sensitivity tests. The effects of the steam properties are also examined. Three scenarios are used to illustrate the steam injection method: normal reservoir model, hydraulically fractured reservoir model, and horizontal injector wells. The use of hydraulic fracture from the model results in a 20% increase of oil recovery compared to the normal reservoir model. The parameters used for sensitivity tests are fracture parameters such as fracture length and fracture width, and steam properties. The sensitivity tests indicate that parameters such as injection pressure and fracture scheduling have a big impact on increasing the oil recovery during the fracture-assisted steam flooding process. The optimum result is generated from the fracture-assisted steam flooding scenario with a sensitivity of fracture schedule and higher injection pressure. This study proves that improvements in the effectiveness of the steam injection process in heavy oil reservoirs can be achieved. It also presents a unique approach to improve steam-oil exposures by applying horizontal injector wells. This paper introduces the effect of an alternative approach to apply fracture-assisted flooding in the steam injection process. The paper also discusses the best scenario for steam injection by combining the sensitivity of steam and fracture parameters. Both combinations will affect the increase of oil recovery by 25-30% from the base case scenario.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"99 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123030704","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The Arang Petroleum Play in The West Natuna Basin: A New Perspective From Geochemical Study and Petroleum System Modelling","authors":"F. Kusdiantoro","doi":"10.29118/ipa22-g-67","DOIUrl":"https://doi.org/10.29118/ipa22-g-67","url":null,"abstract":"One of the main producing gas reservoirs in the Medco E&P Natuna Ltd.’s (Medco E&P) operated South Natuna Sea Block B PSC (Block B) is the shallow Miocene Arang Formation (Arang reservoir or Arang). The main characteristics of the Arang gas is the dominance of the dry component. The previous understanding was that the gas was generated from the Arang intra-formational shale source rock. An integrated geochemical and regional 3D petroleum system model has been conducted over the Block B area. This effort suggests that the main contributing source rock to the Arang reservoir is in fact the syn-rift Belut Formation. The study also aimed at locating the potential areas for primary microbial gas accumulation in the Arang reservoir, especially where traps are not connected to thermogenic kitchens. The results of composition analysis from producing Arang gas show variable compositions from dry gas only to gas with small amount of oil. Gas wetness appears to increase with proximity to thermogenic kitchen. The carbon isotope values of the gas fraction in the Arang reservoir suggests mainly a thermogenic gas origin with additional primary microbial gas characterized by much lighter Carbon isotope ratios. This study concludes that the thermogenic Arang gas originate from multiple source rocks with various maturity levels ranging from early to late maturity stage, mixed with some paleo biogenic gas. The Belut source rock has reached an adequate maturity level to generate gas in some sub-basins such as the Bawal, Belanak and Belut Grabens. Despite Arang has reached early to peak maturity oil window in Block B, the low expulsion value disregards the Arang as a key contributor for hydrocarbon generation and expulsion in Block B. The majority of the discoveries and producing gas fields from the Arang reservoir are located above the mature Belut Kitchen. The fact that there are some Arang discoveries away from mature kitchen suggest that lateral migration also occurred within the Arang.. Complex vertical and lateral migration-remigration process within the Arang is a result of interplay between continuous structural growth and possible seal integrity change during the syn-inversion period.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"84 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122644044","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Quadruple Well Production Optimization By ESP Upsizing","authors":"A. Aryanto","doi":"10.29118/ipa22-e-267","DOIUrl":"https://doi.org/10.29118/ipa22-e-267","url":null,"abstract":"Electric Submersible Pump (ESP) upsizing project has historically an effective tool to optimize oil production. As a mature field, SK field currently was producing with average 97% water cut. Most of the ESPs installed in SK field were designed to produce 1,000 to 2,500 BLPD. Meanwhile, the potential maximum liquid rate of some wells is much higher than the current ESP rate, ranging from 8,000 to 17,000 BLPD. The oil production can then potentially be increased 3 to 5 times higher by upsizing the ESP. Hence, the objective of this study is to accelerate oil recovery from un-optimum oil well. This optimization can be achieved in 2 ways, either drill new big bore well or optimize existing well. By optimizing existing wells through ESP upsizing pilot project, we can save estimated USD 1.5 MM compared to drill a new well. The ESP upsizing project is planned into 3 phases; phase-1 pilot (2 wells), phase-2 implementation (6 wells) and phase-3 full-scale (35 wells). SK-354 and SK-225 were selected for the pilot project and upsized using ESP pump with recommended operating range 3,500 – 10,500 BLPD at 60Hz. The reservoir simulation, fractional flow evaluation, production network modelling, well performance and nodal analysis were conducted prior phase-1 execution to increase project confident level. To operate these high-rate wells, some improvements in electrical system, flowline safety devices and well test procedure are also required. Therefore, multidiscipline team was involved in this project. The pilot project phase-1 has successfully executed and currently producing 476 BOPD from initial rate 80 BOPD without significantly increasing of water cut. Estimated cumulative oil gain of these wells are 567 MBO. The successful phase-1 ESP upsizing will unlock the potency of phase-2 and 3. Through maximizing liquid production and reducing number of active ESP wells, oil production is expected to increase with lower operating cost (by reducing well count). Estimated oil gain from phase-2 & 3 implementation is 4.93 MMBO.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125206318","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The Biggest Risks in Hydrocarbon Exploration That are Often Overlooked: Cases of Exploration Failures in Indonesia and The Solutions","authors":"A. H. Satyana","doi":"10.29118/ipa22-g-312","DOIUrl":"https://doi.org/10.29118/ipa22-g-312","url":null,"abstract":"Petroleum system analysis is a method commonly used by geoscientists to assess the possibility of an area containing petroleum. But the levels of analysis of the elements and processes of a petroleum system are often unbalanced. Some aspects are analysed in detail while others are overlooked. These overlooked aspects often turn out to carry the highest risks for exploration. The author reviewed multiple cases of exploration failures in Indonesia post-2000 and found that these failures are generally related to an overlook of some elements and processes of the petroleum system. This includes the tendency to think of seismic low as a kitchen, being too optimistic in doing basin modelling, assuming that it is sufficient if kitchens have generated hydrocarbons whereas expulsion threshold is more critical, not mapping migration pathways in detail, and not evaluating carrier beds and regional sealing. Revisiting the petroleum system analysis method, carrying out a more balanced analysis for all elements and processes of the petroleum system, and reconstructing it with the tectono-sedimentary evolution of the basin where the exploration area is located from its formation to the present day (dynamic interpretation) are the solutions offered. Hopefully these solutions can reduce exploration failures and increase success in Indonesia and other areas.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"18 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125551631","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"An Integrated Approach of CO2 Injection and Storage Assessment in Tight Gas Condensate Carbonate Reservoir, Case Study: Central Kalimantan, Indonesia","authors":"A. Magfirah","doi":"10.29118/ipa22-se-306","DOIUrl":"https://doi.org/10.29118/ipa22-se-306","url":null,"abstract":"Geological storage is a potential solution for storing carbon dioxide (CO2) emissions from stationary sources such as fossil-fuel-fired power stations over lengthy periods. The typical geological formation for storage is a massive saline aquifer or oil and gas reservoir with good permeability (>100 mD). However, what if the targeted geological formation is a massive reservoir with tight properties (<0.1 mD)? Does it have the potential to store CO2? Currently, the study of CO2 storage in a tight reservoir is limited. Therefore, this study presents a comprehensive subsurface analysis of CO2 storage potential in a tight gas condensate carbonate reservoir located in Central Kalimantan, Indonesia. The study analyzes the characteristics of CO2 injection and storage in tight formation, which covers the entire GGR (geology, geophysics, reservoir) aspects. The reservoir is a platform carbonate and based on the geoscience assessment the reservoir can be clustered into several depositional elements (DE), such as reef complex and platform interior. A static & dynamic model is created to capture the reservoir behavior, variations, and physics. As such, it is utilized to assess the field's effective storage capacity, reservoir injectivity, CO2 plume migration, pressure connection potential, CO2 breakthrough phenomena, and stimulation effectiveness. Additionally, coupled reservoir-geomechanical models are also performed to assess the relevant geomechanical concerns upon three separate phases of pre-injection, during injection, and after injection/monitoring. Initially, a well-calibrated 3D compositional reservoir model is prepared for performing a series of CO2 injection scenarios. It is started by performing a well-by-well assessment and continued by a full-field assessment. Firstly, the sensitivity of well locations indicates that the reef complex has higher injectivity five times compared to the platform interior. However, the CO2 injected into the reef complex also has a quicker breakthrough to the producer wells than the other DE-s. Moreover, the streamline analysis confirms this finding by showing distinct features of pressure path and flow behavior. Subsequently, the sensitivity of well stimulation treatment is also performed. The wells with acid fracturing stimulation can deliver double the injectivity of untreated wells. As for the full-field assessment, the coupled reservoir-geomechanical model is calibrated by a series of rock mechanic tests (triaxial, uni-axial pore volume compressibility, and permeability under a series of confining stresses). These tests indicate that the reservoir consists of hard rock (>3 million psi Young’s Modulus) and behaves as an intact structure until the end of the injection period. Overall, this study of CO2 Injection and Storage in a tight gas reservoir shows that this formation has the potential to store the CO2. Neither injectivity issues nor geomechanical risks are forecasted for the optimized injection. Finally, the","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention &amp; Exhibition, 2022","volume":"81 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126274851","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"2D Seismic and Well Log Data Integration to Predict Pore Pressure Distribution in Brilian Field, Bintuni Basin","authors":"R. V","doi":"10.29118/ipa22-sg-137","DOIUrl":"https://doi.org/10.29118/ipa22-sg-137","url":null,"abstract":"Accurate pore pressure prediction in drilling activities supports the safety and economic aspects of avoiding loss, kick, or blowout. This is more so when the drilling is carried out in limestone lithology with various pore pressures in the same formation. Bintuni Basin is one of the productive basins in Eastern Indonesia, with limited pore pressure predictions in the Steenkool Formation. Brilliant Field in Bintuni Basin has been actively producing hydrocarbon from limestone lithology in the Kais Formation since 1981, with the least pore pressure prediction. Integration of 2D seismic data and well data has been carried out to obtain more accurate pore pressure distribution in Kais Formation, Brilian Field, Bintuni Basin. Pore pressure prediction uses Eaton's empirical approach to the relationship between formation resistivity values and pore pressure to depth. Prediction of 1D pore pressure in wells R-3, R-4, R-5, and RD-1 shows that the pore pressure distribution tends to be hydrostatically normal, which is validated by plotting mud weight data, drilling events, and gas readings for each well. 2D seismic and well data integration results show that high porosity is randomly distributed due to the dolomitization process and aragonite dissolution. Meanwhile, low porosity values are associated with thin shale and clay lithology that spread laterally at the top of Kais Formation due to transgression and overflow from the Sekau Reefal zone. Pore pressure distribution based on integrating 2D seismic data and well data in the Kais Formation, Brilian Field, Bintuni Basin laterally tends to be homogeneous. It normally increases with increasing depth in terms of no indication of a drastic increase or decrease in pressure values.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention &amp; Exhibition, 2022","volume":"32 10 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125708153","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}