Forecasting reservoir performances during the carbon capture, utilization, and storage (CCUS) operations is essential to monitor the amount of incremental oil recovered and CO2 trapped. This paper proposes predictive data-driven models for forecasting oil, CO2, and water production on the existing wells and future infill well utilizing long short-term memory (LSTM) networks, a deep learning variant for time series modeling. Two models are developed based on the number of phases referred to: 3-phases (3P) and 1-phase (1P), one interest phase at a time. The models are trained on the dataset from multiple wells to account for the effect of interference of neighboring wells based on the inverse distance to the target well. The performance of the models is evaluated using walk-forward validation and compared based on quality metrics and length and consistency of the forecasting horizon. The results suggest that the 1P models demonstrate strong generalizability and robustness in capturing multivariate dependencies in the various datasets across eight wells with a long and consistent forecasting horizon. The 3P models have a shorter and comparable forecasting horizon. The 1P models show promising performances in forecasting the fluid production of future infill well when developed from the existing well with similar features to the infill well. The proposed approach offers an alternative to the physics-driven model in reservoir modeling and management and can be used in situations when conventional modeling is prohibitively expensive, slow, and labor-intensive.
{"title":"Long Short-term Memory (LSTM) Networks for Forecasting Reservoir Performances in Carbon Capture, Utilisation, and Storage (CCUS) Operations","authors":"U. Iskandar, M. Kurihara","doi":"10.29017/scog.45.1.943","DOIUrl":"https://doi.org/10.29017/scog.45.1.943","url":null,"abstract":"Forecasting reservoir performances during the carbon capture, utilization, and storage (CCUS) operations is essential to monitor the amount of incremental oil recovered and CO2 trapped. This paper proposes predictive data-driven models for forecasting oil, CO2, and water production on the existing wells and future infill well utilizing long short-term memory (LSTM) networks, a deep learning variant for time series modeling. Two models are developed based on the number of phases referred to: 3-phases (3P) and 1-phase (1P), one interest phase at a time. The models are trained on the dataset from multiple wells to account for the effect of interference of neighboring wells based on the inverse distance to the target well. The performance of the models is evaluated using walk-forward validation and compared based on quality metrics and length and consistency of the forecasting horizon. The results suggest that the 1P models demonstrate strong generalizability and robustness in capturing multivariate dependencies in the various datasets across eight wells with a long and consistent forecasting horizon. The 3P models have a shorter and comparable forecasting horizon. The 1P models show promising performances in forecasting the fluid production of future infill well when developed from the existing well with similar features to the infill well. The proposed approach offers an alternative to the physics-driven model in reservoir modeling and management and can be used in situations when conventional modeling is prohibitively expensive, slow, and labor-intensive.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"40 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87571087","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}
Presence of heavy-conductive mineral(s) in formation rocks tends to provide negative influence to some log readings especially the resistivity log. With regard to its function in log analysis, any distortion in resistivity log readings will certainly lead to potential misinterpretation on petrophysical properties such as water saturation (S.) Therefore a method dedicated to minimizing the effect is indeed necessary.This paper presents results of a study on presence of heavy-conductive minerals, distributed in structural form, on resistivity reading. Based on analogy and expansion of a structural clay distribution model, a correction method plus its application procedure have been proposed. Since the method is develop using an approach that is considered valid in general term it is, therefore, conceptually applicable to any field cases as long as its theoretical conditions are met. In order to make application of the method easier it has also been presented in form of nomographs.Application of the method on log analysis of two wells in West Java has proved itself well in which corrections on calculated water saturation have yielded values that are more consistent when compared to production test data. The method is also prepared in a manner that it can be easily integrated into standard log analysis practices.
{"title":"Reducing Uncertainty In Log Analysis Due To Presence Of Heavy-Conductive Minerals In Sendimentary Rocks","authors":"B. Widarsono","doi":"10.29017/scog.23.1.880","DOIUrl":"https://doi.org/10.29017/scog.23.1.880","url":null,"abstract":"Presence of heavy-conductive mineral(s) in formation rocks tends to provide negative influence to some log readings especially the resistivity log. With regard to its function in log analysis, any distortion in resistivity log readings will certainly lead to potential misinterpretation on petrophysical properties such as water saturation (S.) Therefore a method dedicated to minimizing the effect is indeed necessary.This paper presents results of a study on presence of heavy-conductive minerals, distributed in structural form, on resistivity reading. Based on analogy and expansion of a structural clay distribution model, a correction method plus its application procedure have been proposed. Since the method is develop using an approach that is considered valid in general term it is, therefore, conceptually applicable to any field cases as long as its theoretical conditions are met. In order to make application of the method easier it has also been presented in form of nomographs.Application of the method on log analysis of two wells in West Java has proved itself well in which corrections on calculated water saturation have yielded values that are more consistent when compared to production test data. The method is also prepared in a manner that it can be easily integrated into standard log analysis practices.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"40 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80584172","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}
A detailed understanding regarding the rocks Brittleness Index is helpful in oil and gas exploration as upfront information to determine the rock fracture gradient. Researchers have proposed several methods to estimate the rock Brittleness Index. However, different ways may yield different results and lead to varying interpretations regarding the Brittleness Index classifi cation. This paper evaluates the Brittleness Index of an Indonesian gas well using three approaches based on the elastic properties log data, elastic properties rock physics modeling, and mineralogical rock physics modeling to assess the consistency of the methods. The results obtained in this study suggest that elastic properties-based and mineralogical methods produced a consistent Brittleness Index. However, the vertical resolution is different. It indicates that the Brittleness Index estimated from the actual log data showed higher resolution than the Brittleness Index calculated from the rock physics modeling. Combining TOC data with the Brittleness Index is recommended to optimize hydraulic fracturing design and planning. For further investigation, the authors will be suggesting direct sampling from cores and laboratory measurements to obtain the in-situ mechanical properties of shale rocks.
{"title":"The Feasibility Study of Reservoir Geomechanics from Brittleness Evaluation","authors":"Benyamin Elilaski Nababan, H. Hutami, F. Fatkhan","doi":"10.29017/scog.45.1.920","DOIUrl":"https://doi.org/10.29017/scog.45.1.920","url":null,"abstract":"A detailed understanding regarding the rocks Brittleness Index is helpful in oil and gas exploration as upfront information to determine the rock fracture gradient. Researchers have proposed several methods to estimate the rock Brittleness Index. However, different ways may yield different results and lead to varying interpretations regarding the Brittleness Index classifi cation. This paper evaluates the Brittleness Index of an Indonesian gas well using three approaches based on the elastic properties log data, elastic properties rock physics modeling, and mineralogical rock physics modeling to assess the consistency of the methods. The results obtained in this study suggest that elastic properties-based and mineralogical methods produced a consistent Brittleness Index. However, the vertical resolution is different. It indicates that the Brittleness Index estimated from the actual log data showed higher resolution than the Brittleness Index calculated from the rock physics modeling. Combining TOC data with the Brittleness Index is recommended to optimize hydraulic fracturing design and planning. For further investigation, the authors will be suggesting direct sampling from cores and laboratory measurements to obtain the in-situ mechanical properties of shale rocks.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"54 37 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80585154","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}
The in situ state of stress is a rock's point-to-point property that must be taken into consideration in every subsurface engineering activity This has been realized to an increasing extent over the past 10 - 20 years. Good quality in situ stress information enhances the quality of engineering designs such ax for mining, petroleum and geothermal production. In turn good engineering designs will support the process of decision making in related industries. However, efforts are required to encourage the use and integration of this information into the engineering activities.This paper is basically a general review over the in situ stress that encompasses various aspects, among others are concept, causes/sources that generate it, influencing factors, the effect of scales, techniques for measuring it, and its distribution throughout the lithosphere. The review is supported by works and conclusions that have been made by various investigators in the past. The relative absence of the use of in situ stress information in petroleum engineering practices in Indonesia is also discussed. This includes the absence of demand upon the information, probable consequence, and the field cases that are likely caused by the absence.Apart from the importance of in situ stress information shown by the review, it has also prompted the need to apply proper use of in situ stress information in relation to the corresponding engineering scales. Inappropriate measurement techniques assigned to an engineering problem, which corresponds to a certain scale, will certainly lead to a serious misprediction over the expected outcome. These all are hoped to provide operators in the industry a complete general view over the in situ stresses their importance.
{"title":"In-Situ Stresses In Rock Masses: A General Review","authors":"B. Widarsono","doi":"10.29017/scog.23.2.881","DOIUrl":"https://doi.org/10.29017/scog.23.2.881","url":null,"abstract":"The in situ state of stress is a rock's point-to-point property that must be taken into consideration in every subsurface engineering activity This has been realized to an increasing extent over the past 10 - 20 years. Good quality in situ stress information enhances the quality of engineering designs such ax for mining, petroleum and geothermal production. In turn good engineering designs will support the process of decision making in related industries. However, efforts are required to encourage the use and integration of this information into the engineering activities.This paper is basically a general review over the in situ stress that encompasses various aspects, among others are concept, causes/sources that generate it, influencing factors, the effect of scales, techniques for measuring it, and its distribution throughout the lithosphere. The review is supported by works and conclusions that have been made by various investigators in the past. The relative absence of the use of in situ stress information in petroleum engineering practices in Indonesia is also discussed. This includes the absence of demand upon the information, probable consequence, and the field cases that are likely caused by the absence.Apart from the importance of in situ stress information shown by the review, it has also prompted the need to apply proper use of in situ stress information in relation to the corresponding engineering scales. Inappropriate measurement techniques assigned to an engineering problem, which corresponds to a certain scale, will certainly lead to a serious misprediction over the expected outcome. These all are hoped to provide operators in the industry a complete general view over the in situ stresses their importance.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"37 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75196234","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}
The palynological investigation focuses on the transition sediment of the Lower Kalipucang Formation which overlies the non-marine lava of the Gabon Formation. Both formations are firmly separated by the unconformity which is indicated by the occurrence of basal conglomerate. The Lower Kalipucang Formation outcrops in a small village called Tlogosari, Central Java. Lithologically, it is characterised by the occurrence of basal conglomerate with the intercalation of thin lignites. This lithology is overlain by 2 meter thick of claystone containing lignite strings and some igneous fragments. The intercalation of thin sandstones, conglomerate and lignites are found within claystone lithology. Four samples from the Lower Kalipucang Formation were selected for laboratory processing. Only two samples collected from the upper part of this formation yield rich palynomorphs. The palynomorph assemblage shows the occurrence of brackish and fresh water floras. Based on the appearance of pollen Florschuetzia meridionalis and F. trilobata, it is predicted that the age of the Lower Kalipucang Formation is Middle Miocene. The high abundance of mangrove taxa (especially in sample number LKP-4) such as Avicenia type, Zonocostites ramonae and Camptostemon indicates a well development of mangrove environment. This assumption is supported by well preservation of large mollusc with excellent ornamentation. This ornamentation must have developed in the environment with low energy such as mangrove.
{"title":"Palynology Of The Lower Kalicapung Formation Tlogosari, Central Java","authors":"E. B. Lelono","doi":"10.29017/scog.25.2.878","DOIUrl":"https://doi.org/10.29017/scog.25.2.878","url":null,"abstract":"The palynological investigation focuses on the transition sediment of the Lower Kalipucang Formation which overlies the non-marine lava of the Gabon Formation. Both formations are firmly separated by the unconformity which is indicated by the occurrence of basal conglomerate. The Lower Kalipucang Formation outcrops in a small village called Tlogosari, Central Java. Lithologically, it is characterised by the occurrence of basal conglomerate with the intercalation of thin lignites. This lithology is overlain by 2 meter thick of claystone containing lignite strings and some igneous fragments. The intercalation of thin sandstones, conglomerate and lignites are found within claystone lithology. Four samples from the Lower Kalipucang Formation were selected for laboratory processing. Only two samples collected from the upper part of this formation yield rich palynomorphs. The palynomorph assemblage shows the occurrence of brackish and fresh water floras. Based on the appearance of pollen Florschuetzia meridionalis and F. trilobata, it is predicted that the age of the Lower Kalipucang Formation is Middle Miocene. The high abundance of mangrove taxa (especially in sample number LKP-4) such as Avicenia type, Zonocostites ramonae and Camptostemon indicates a well development of mangrove environment. This assumption is supported by well preservation of large mollusc with excellent ornamentation. This ornamentation must have developed in the environment with low energy such as mangrove.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"29 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82278439","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}
Reservoir rock physical properties, such as porosity and water saturation, always play prominent roles in the development of oil and gas fields. Accurate information regarding their distribution is always desired. For this new approach that uses a purpose, a combination of intelligent computing (artificial neural network or ANN) and rock physics, with a full utilization of core data, well logs and seismic-derived attributes, is proposed. The method is basically an effort to link the required rock physical properties to seismic- derived attributes through the use of rock physics theories. The ANN itself is used to fill the gaps of data array required by the proposed method through its capacity for pattern recognition. The proposed method is applied to a limestone reservoir in East Java. Validation is carried out by comparing the results to the observed data at well locations as well as by geological justification. The application has shown a new potential for supporting reservoir modeling and field development.
{"title":"Application of Artificial Neural Network for Assisting Seismic-Based Reservoir Characterization","authors":"B. Widarsono, F. Saptono, P. Wong, S. Munadi","doi":"10.29017/scog.25.1.879","DOIUrl":"https://doi.org/10.29017/scog.25.1.879","url":null,"abstract":" Reservoir rock physical properties, such as porosity and water saturation, always play prominent roles in the development of oil and gas fields. Accurate information regarding their distribution is always desired. For this new approach that uses a purpose, a combination of intelligent computing (artificial neural network or ANN) and rock physics, with a full utilization of core data, well logs and seismic-derived attributes, is proposed. The method is basically an effort to link the required rock physical properties to seismic- derived attributes through the use of rock physics theories. The ANN itself is used to fill the gaps of data array required by the proposed method through its capacity for pattern recognition. The proposed method is applied to a limestone reservoir in East Java. Validation is carried out by comparing the results to the observed data at well locations as well as by geological justification. The application has shown a new potential for supporting reservoir modeling and field development.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"9 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89807540","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}
Originally Drill Stem Test (DST), as an evaluation tool, was only an indicator of type of fluid production. Interest in the DST as a modern evaluation tool was revived when certain theoretical equations were proven as a means of calculating values for important formation parameters. This paper is an example, the basic interpretation method, that will prepare the geologist and engineer for more sophisticated approaches that are sure to come, It is proposed of this paper to show how DST data might be Ned to make certain reservoir parameter de- terminations, in field works.
{"title":"Dst Data Evaluation In Practice","authors":"Herlan Adim","doi":"10.29017/scog.25.3.877","DOIUrl":"https://doi.org/10.29017/scog.25.3.877","url":null,"abstract":"Originally Drill Stem Test (DST), as an evaluation tool, was only an indicator of type of fluid production. Interest in the DST as a modern evaluation tool was revived when certain theoretical equations were proven as a means of calculating values for important formation parameters. This paper is an example, the basic interpretation method, that will prepare the geologist and engineer for more sophisticated approaches that are sure to come, It is proposed of this paper to show how DST data might be Ned to make certain reservoir parameter de- terminations, in field works.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"68 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73711653","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}
Water injection is often used to keep maintaining reservoir pressure. Injected water (high in sulphate) mixes with formation water (high in barium) leading to the deposition of barium sulfate scale in the near wellbore, reservoir, production tubulars and topside equipment. Barium sulfate scale is unique scale deposit and the least soluble of the scales. The deposition of oil field scale is a potentially damaging problem which reduces fluid flow resulting in a decline in oil production. The best approach to solving the problems of scale formation is to prevent or inhibit deposition and this is more effective than scale removal. The use of scale inhibitor can be effective method for preventing scalealthough their effectiveness is controlled by experimental conditions. Therefore, it is very important to know factors that influence barium sulfate scale. The maintopic of this paper is “The Influence of pH and Concentration of Inhibitor Solution - Tests on Change of Barium Sulfate Scale Morphology by Using Scanning Electron Microscope”. Hopefully, the results of laboratory test presented this paper give useful and valuable information not only for LEMIGAS, but also for oil industry, chemical manufacturers and universities, then other institutions.
{"title":"The Influence Of Ph And Concentration Of Phosphonate Inhibitor - Tests On Change Of Barium Sulfate Scale Morphology By Using Scanning Electron Microscope","authors":"Tjuwati Makmur","doi":"10.29017/scog.27.2.873","DOIUrl":"https://doi.org/10.29017/scog.27.2.873","url":null,"abstract":"Water injection is often used to keep maintaining reservoir pressure. Injected water (high in sulphate) mixes with formation water (high in barium) leading to the deposition of barium sulfate scale in the near wellbore, reservoir, production tubulars and topside equipment. Barium sulfate scale is unique scale deposit and the least soluble of the scales. The deposition of oil field scale is a potentially damaging problem which reduces fluid flow resulting in a decline in oil production. The best approach to solving the problems of scale formation is to prevent or inhibit deposition and this is more effective than scale removal. The use of scale inhibitor can be effective method for preventing scalealthough their effectiveness is controlled by experimental conditions. Therefore, it is very important to know factors that influence barium sulfate scale. The maintopic of this paper is “The Influence of pH and Concentration of Inhibitor Solution - Tests on Change of Barium Sulfate Scale Morphology by Using Scanning Electron Microscope”. Hopefully, the results of laboratory test presented this paper give useful and valuable information not only for LEMIGAS, but also for oil industry, chemical manufacturers and universities, then other institutions.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"33 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73781843","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}
This study demonstrates the ability of palynology in helping explorationist to comprehend the stratigraphic framework of the middle Miocene formation in the Sangatta area. Palynological analysis is performed on three different wells which are called X, Y and Z. With the exception of the samples situated in the lower part of the studied wells, most samples yield excellent palynomorph assemblages. High abundance of mangrove pollen suggests a good development of mangrove forest which indicates the occurrence of deltaic sediments within these three wells. The studied wells have been correlated based on the abundance of mangrove pol- len Zonocostites ramonae and freshwater swamp pollen Ilexpollenites sp. This correlation allows reconstruction of the local palynological scheme for the Sangata area. The combination between quantitative palynological analysis and litological data (inferred from well logs) allows interpretation of sequence stratigraphic units including transgressive and highstand units. These units separate the studied sediments into three progradational units (Units 1, 2 and 3) which figure out the development of Middle Miocene deltaic facies in the Sangata area.
{"title":"Stratigraphic Interpretation Of The Middle Miocene Deltaic Sediment In The Sangatta Area, Based On Quantitative Palynological Data","authors":"E. B. Lelono","doi":"10.29017/scog.26.2.876","DOIUrl":"https://doi.org/10.29017/scog.26.2.876","url":null,"abstract":"This study demonstrates the ability of palynology in helping explorationist to comprehend the stratigraphic framework of the middle Miocene formation in the Sangatta area. Palynological analysis is performed on three different wells which are called X, Y and Z. With the exception of the samples situated in the lower part of the studied wells, most samples yield excellent palynomorph assemblages. High abundance of mangrove pollen suggests a good development of mangrove forest which indicates the occurrence of deltaic sediments within these three wells. The studied wells have been correlated based on the abundance of mangrove pol- len Zonocostites ramonae and freshwater swamp pollen Ilexpollenites sp. This correlation allows reconstruction of the local palynological scheme for the Sangata area. The combination between quantitative palynological analysis and litological data (inferred from well logs) allows interpretation of sequence stratigraphic units including transgressive and highstand units. These units separate the studied sediments into three progradational units (Units 1, 2 and 3) which figure out the development of Middle Miocene deltaic facies in the Sangata area.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"88 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88621065","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}
Water flooding, in many mature fields is facing a common problem of low sweep efficiency in the late production period. The breakthrough of injection water is very early when high permeability streaks or thief zones exist in the formation, and resulted in excessive water production. Two kind of technologies commonly are used to modify the permeability streak i.e. MPM (Microbial Profile Modification), and polymer gel with cross linkers material. A new technology which is called Bright Water has been intensively studied. Bright Water is capable of in-depth placement into high permeability streaks in the reservoir. To improve the water flood sweep efficiency, studies of examination a fluid injection design have been evaluated. The objective of this study is to set-up core flooding tests and to determine the effective- ness of the Bright Water to reduce the permeability, and also include optimization of Bright Water formulation, resistance factor determination, and gelling time evaluation.
{"title":"Development Of Waterflood Profile Modification Using Brightwater Technology","authors":"Sugihardjo Sugihardjo","doi":"10.29017/scog.28.3.871","DOIUrl":"https://doi.org/10.29017/scog.28.3.871","url":null,"abstract":"Water flooding, in many mature fields is facing a common problem of low sweep efficiency in the late production period. The breakthrough of injection water is very early when high permeability streaks or thief zones exist in the formation, and resulted in excessive water production. Two kind of technologies commonly are used to modify the permeability streak i.e. MPM (Microbial Profile Modification), and polymer gel with cross linkers material. A new technology which is called Bright Water has been intensively studied. Bright Water is capable of in-depth placement into high permeability streaks in the reservoir. To improve the water flood sweep efficiency, studies of examination a fluid injection design have been evaluated. The objective of this study is to set-up core flooding tests and to determine the effective- ness of the Bright Water to reduce the permeability, and also include optimization of Bright Water formulation, resistance factor determination, and gelling time evaluation.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77717479","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}
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