R. Ramadhan, Adi Novriansyah, T. Erfando, S. Tangparitkul, Arik Daniati, A. Permadi, M. Abdurrahman
The production of oil and gas is heavily dependent on the heterogeneity of the reservoir. Optimizing the production plan and maximizing recovery from the reservoir depends on an understanding of how heterogeneity affects fluid flow and recovery. Techniques such as water flooding and polymer flooding were used to increase oil production from reservoirs while evaluating the impact of reservoir heterogeneity. Numerical simulations in homogeneous and heterogeneous models were performed in this research to identify the optimal operational parameters that will optimize oil recovery and assess the effect of heterogeneity in the reservoir on the recovery factor of the reservoir. The result showed that the homogeneous model obtained 59.86% of the oil recovery factor, while the heterogeneous reservoirs for Lk = 0.2, 0.4, and 0.6 resulted from 45.83%, 69.27%, and 80.46% of oil recovery after twenty years of production, respectively. The heterogeneous reservoir with Lk = 0.6 indicated the highest sweep efficiency compared to other scenarios, while the reservoir with Lk = 0.2 showed the lowest sweep efficiency
{"title":"Heterogeneity Effect on Polymer Injection: a Study of Sumatra Light Oil","authors":"R. Ramadhan, Adi Novriansyah, T. Erfando, S. Tangparitkul, Arik Daniati, A. Permadi, M. Abdurrahman","doi":"10.29017/scog.46.1.1334","DOIUrl":"https://doi.org/10.29017/scog.46.1.1334","url":null,"abstract":"The production of oil and gas is heavily dependent on the heterogeneity of the reservoir. Optimizing the production plan and maximizing recovery from the reservoir depends on an understanding of how heterogeneity affects fluid flow and recovery. Techniques such as water flooding and polymer flooding were used to increase oil production from reservoirs while evaluating the impact of reservoir heterogeneity. Numerical simulations in homogeneous and heterogeneous models were performed in this research to identify the optimal operational parameters that will optimize oil recovery and assess the effect of heterogeneity in the reservoir on the recovery factor of the reservoir. The result showed that the homogeneous model obtained 59.86% of the oil recovery factor, while the heterogeneous reservoirs for Lk = 0.2, 0.4, and 0.6 resulted from 45.83%, 69.27%, and 80.46% of oil recovery after twenty years of production, respectively. The heterogeneous reservoir with Lk = 0.6 indicated the highest sweep efficiency compared to other scenarios, while the reservoir with Lk = 0.2 showed the lowest sweep efficiency","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"28 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75181365","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}
T. M. Susantoro, S. Suliantara, A. B. Harto, H. Setiawan, Gatot Nugroho, D. S. Candra, Adis Jayati, S. Sulma, M. Khomarudin, R. Arief, Ahmat Maryanto, Y. F. Hestrio, Kurdianto Kurdianto
Oil and gas are important commodities in Indonesia and remain the main source for energy in various sectors. Therefore, the government aim to produce 1 million barrels of oil per day (BOPD) by 2030. To achieve this goal, exploration work is needed to discover new reserves and maintain production in existing fields. This study reviews the experience of oil and gas exploration in Indonesia using remote sensing data and the potential of using remote sensing data for oil and gas exploration through surface anomalies. Surface anomalies are changes or deviations that occur on the surface as the result of the presence of oil and gas underneath. These anomalies included vegetation growing stunted, yellowing or dying, changes in the quantity and composition of clay minerals, iron oxide, increased concentrations of hydrocarbons, helium, radon, carbon dioxide, microbes, and the presence of paraffin dirt formation, as well as geomorphological changes. This study aims to assess and explain the capabilities of remote sensing data in Indonesia for oil and gas exploration. The results show that remote sensing can be used for the initial exploration of oil and gas by delineating areas of potential oil and gas traps based on topographical anomalies and geological mapping integrated with gravity data and increasing confidence in the presence of oil and gas in the subsurface based on surface anomalies. These results are expected that the usefulness of remote sensing can be used to support oil and gas exploration in Indonesia and can be recognized and used for oil and gas activities by utilizing existing methods and discovering methods for data processing and their applications.
{"title":"The Potential of Remote Sensing Data for Oil and Gas Exploration in Indonesia: a Review","authors":"T. M. Susantoro, S. Suliantara, A. B. Harto, H. Setiawan, Gatot Nugroho, D. S. Candra, Adis Jayati, S. Sulma, M. Khomarudin, R. Arief, Ahmat Maryanto, Y. F. Hestrio, Kurdianto Kurdianto","doi":"10.29017/scog.46.1.1346","DOIUrl":"https://doi.org/10.29017/scog.46.1.1346","url":null,"abstract":"Oil and gas are important commodities in Indonesia and remain the main source for energy in various sectors. Therefore, the government aim to produce 1 million barrels of oil per day (BOPD) by 2030. To achieve this goal, exploration work is needed to discover new reserves and maintain production in existing fields. This study reviews the experience of oil and gas exploration in Indonesia using remote sensing data and the potential of using remote sensing data for oil and gas exploration through surface anomalies. Surface anomalies are changes or deviations that occur on the surface as the result of the presence of oil and gas underneath. These anomalies included vegetation growing stunted, yellowing or dying, changes in the quantity and composition of clay minerals, iron oxide, increased concentrations of hydrocarbons, helium, radon, carbon dioxide, microbes, and the presence of paraffin dirt formation, as well as geomorphological changes. This study aims to assess and explain the capabilities of remote sensing data in Indonesia for oil and gas exploration. The results show that remote sensing can be used for the initial exploration of oil and gas by delineating areas of potential oil and gas traps based on topographical anomalies and geological mapping integrated with gravity data and increasing confidence in the presence of oil and gas in the subsurface based on surface anomalies. These results are expected that the usefulness of remote sensing can be used to support oil and gas exploration in Indonesia and can be recognized and used for oil and gas activities by utilizing existing methods and discovering methods for data processing and their applications.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"6 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82084055","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 process hydrocracking methyl ester of palm oil into fractions biogasoline by faujasite cata-lyst of fly ash impregnated with nickel have been made. Preparation for faujasite synthesis of fly ash can bedone by removing organic compound and refluxing HCl. Synthesis do by melting the fly ash which has beenprepared with NaOH 1: 1.2 and in aging for 8 hours and in the hydrothermal autoclave for 24 hours. The char-acter faujasite using XRD and Si / Al ratio produces crystallinity main peak of 67% and Si / Al ratio of 1.65.Hydrocracking process using a variety of 4 catalyst used fly ash leaching results, faujasite, Ni-Faujasite 2%, andNi-Faujasite 4%. Test the activity and selectivity of the catalyst to produce liquid product analyzed by GC-MSwith the best catalyst was Ni-Faujasite 4% to yield 42.34% of the activity and selectivity of biogasoline frac-tion of 7.12%. The impregnation of the nickel catalyst is made by soaking in salt of nickel and then oxidationusing O2 gas and reduction using H2 gas. The impregnation of nickel will affect the character of the catalystso that the activity and selectivity of the catalyst is changed. The impregnation of nickel 4% on faujasite suc-cessfully done with nickel content of 3.71%, increasing Si / Al ratio of 2.27 and an acidity of 0.0035 mol/g.
{"title":"Converting Catalytic Palm Oil (MEPO) to Produce Biogasoline Using Zeolite Faujasite Catalyst From Fly Ash with Nickel Impregnation (Ni)","authors":"Donatus Setyawan Purwo Handoko","doi":"10.29017/scog.45.2.1187","DOIUrl":"https://doi.org/10.29017/scog.45.2.1187","url":null,"abstract":"The process hydrocracking methyl ester of palm oil into fractions biogasoline by faujasite cata-lyst of fly ash impregnated with nickel have been made. Preparation for faujasite synthesis of fly ash can bedone by removing organic compound and refluxing HCl. Synthesis do by melting the fly ash which has beenprepared with NaOH 1: 1.2 and in aging for 8 hours and in the hydrothermal autoclave for 24 hours. The char-acter faujasite using XRD and Si / Al ratio produces crystallinity main peak of 67% and Si / Al ratio of 1.65.Hydrocracking process using a variety of 4 catalyst used fly ash leaching results, faujasite, Ni-Faujasite 2%, andNi-Faujasite 4%. Test the activity and selectivity of the catalyst to produce liquid product analyzed by GC-MSwith the best catalyst was Ni-Faujasite 4% to yield 42.34% of the activity and selectivity of biogasoline frac-tion of 7.12%. The impregnation of the nickel catalyst is made by soaking in salt of nickel and then oxidationusing O2 gas and reduction using H2 gas. The impregnation of nickel will affect the character of the catalystso that the activity and selectivity of the catalyst is changed. The impregnation of nickel 4% on faujasite suc-cessfully done with nickel content of 3.71%, increasing Si / Al ratio of 2.27 and an acidity of 0.0035 mol/g.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"37 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-01-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82145902","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}
Krt Nur Suhascaryo, Halwin Ariandi Siregar, Ridwan Ridwan
The “SRG” Oil Field is located in the South Sumatra basin, and the oil produced is classified as heavy oil and generally water-oil emulsion occurs. As a result of the formation of this emulsion which will cause corrosion of equipment in the field. The samples that have been taken in the field are then investigated in the laboratory of PT Farca Risa Sejahtera. First, perform BSW testing on GS-belimbing and GS-11 oil samples to determine the water content and deposits present in the oil. The second is to determine the ratio of the amount of oil and formation water to be used in subsequent tests. The third selection of demulsifiers for formulation materials is based on the ability of water drop, clear water and interface. The four demulsifier formulations combine the demulsifiers that pass the selection into 5 formulas with the hope of uniting the advantages and covering each other’s shortcomings of each demulsifier that passes the selection. The fifth test is overtreated to determine the appropriate dose for the use of a predetermined demulsifier formula. Emulsion sample testing was also carried out on CGS oil samples (GS-belimbing oil and GS-11) plus the oil present in the pits. The six BSW tests after using the new formula. GSbelimbing has a production rate of ±22,000 BFPD with a water cut value obtained from the separator test in the field and validated by the BSW test in the laboratory of ±92%, the value of oil production in GS Belimbing is ±1760 BOPD. While the GS-11 has a production rate of ±33,000 BFPD with a water cut value of ±91%, the value of oil production in GS 11 is ±2970 BOPD. While the CGS has a fluid production rate of ± 58,000 BFPD with a water cut of ± 90%, the value of oil production at the CGS is ± 5800 BOPD. Formula code H5 with a composition of 10% (F13; water drop) plus 10% (1030; interface) and 80% (F-16; clear water) which was selected for GS-belimbing. The formula with code A1 which has a composition of 80% F-8 plus 10% 1030 and 10% F-16 was chosen for the GS-11. For the CGS, the S5 formula is 10% (F-16 clear water) plus 10% (1030; interface) and 80% (F-8; water drop). The results of the BSW test after the new formula showed that there was no water in the oil in the centrifuge tube and it was stated that the BSW value was close to 0%. There are 3 demulsifier products from the formulation, namely HAS-1 for GS-belimbing, HAS-2 for GS-11, and HAS-3 for CGS plus pit. The amount of HAS-3 demulsifier that needs to be injected into the CGS is 7.31 gallons per day (GPD). The number of HAS-1 demulsifier injected into GS Belimbing was 2.22 GPD, while the number of HAS-2 demulsifier injected into GS-11 was 3.74 GPD
{"title":"Laboratory Studies for The Development of a Demulsifier in Handling Production Fluid Emulsions in The “SRG” Field","authors":"Krt Nur Suhascaryo, Halwin Ariandi Siregar, Ridwan Ridwan","doi":"10.29017/scog.45.2.1189","DOIUrl":"https://doi.org/10.29017/scog.45.2.1189","url":null,"abstract":"The “SRG” Oil Field is located in the South Sumatra basin, and the oil produced is classified as heavy oil and generally water-oil emulsion occurs. As a result of the formation of this emulsion which will cause corrosion of equipment in the field. The samples that have been taken in the field are then investigated in the laboratory of PT Farca Risa Sejahtera. First, perform BSW testing on GS-belimbing and GS-11 oil samples to determine the water content and deposits present in the oil. The second is to determine the ratio of the amount of oil and formation water to be used in subsequent tests. The third selection of demulsifiers for formulation materials is based on the ability of water drop, clear water and interface. The four demulsifier formulations combine the demulsifiers that pass the selection into 5 formulas with the hope of uniting the advantages and covering each other’s shortcomings of each demulsifier that passes the selection. The fifth test is overtreated to determine the appropriate dose for the use of a predetermined demulsifier formula. Emulsion sample testing was also carried out on CGS oil samples (GS-belimbing oil and GS-11) plus the oil present in the pits. The six BSW tests after using the new formula. GSbelimbing has a production rate of ±22,000 BFPD with a water cut value obtained from the separator test in the field and validated by the BSW test in the laboratory of ±92%, the value of oil production in GS Belimbing is ±1760 BOPD. While the GS-11 has a production rate of ±33,000 BFPD with a water cut value of ±91%, the value of oil production in GS 11 is ±2970 BOPD. While the CGS has a fluid production rate of ± 58,000 BFPD with a water cut of ± 90%, the value of oil production at the CGS is ± 5800 BOPD. Formula code H5 with a composition of 10% (F13; water drop) plus 10% (1030; interface) and 80% (F-16; clear water) which was selected for GS-belimbing. The formula with code A1 which has a composition of 80% F-8 plus 10% 1030 and 10% F-16 was chosen for the GS-11. For the CGS, the S5 formula is 10% (F-16 clear water) plus 10% (1030; interface) and 80% (F-8; water drop). The results of the BSW test after the new formula showed that there was no water in the oil in the centrifuge tube and it was stated that the BSW value was close to 0%. There are 3 demulsifier products from the formulation, namely HAS-1 for GS-belimbing, HAS-2 for GS-11, and HAS-3 for CGS plus pit. The amount of HAS-3 demulsifier that needs to be injected into the CGS is 7.31 gallons per day (GPD). The number of HAS-1 demulsifier injected into GS Belimbing was 2.22 GPD, while the number of HAS-2 demulsifier injected into GS-11 was 3.74 GPD","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"74 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-01-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75532976","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}
Polymers are often used to increase oil recovery by improving sweeping efficiency. The screening was carried out as a first step in evaluating the test parameters of several polymers of the Hydrolyzed Polyacrylamide (HPAM) type in fluid and sandstone reservoir rocks. The test was carried out using a reservoir fluid classified as light oil (35°API) and at a reservoir temperature (60°C). The HPAM polymers used are A1, F1, F2, F3, and P1 polymers. The test parameters carried out on these 5 types of polymer (A1, F1, F2, F3 dan P1) include a compatibility test for formation water. The rheology polymer test includes concentration vs Tres, and shear rate vs viscosity which aims to determine the type of polymer solution being tested is a non-Newtonian or pseudoplastic fluid group. Thermal stability test of polymer for 60 days to determine the stability of the polymer solution and whether it is degraded or stable. Filtration testing with criteria FR value 1.2, screen factor test, and adsorption testing using the static method with a standard limit of adsorption value 400 µg/gr and polymer injectivity test. From these tests, scoring (range 0-100) was carried out to determine polymer candidates in polymer flooding testing. The F1 polymer candidate for the sandstone reservoir was obtained with a score of 82.25. From the scoring results, the selected F1 polymer candidate has a concentration value of 2000 ppm. For thermal degradation, the polymer F1 2000 ppm experienced degradation of 15.5%. The results of the F1 2000 ppm polymer static adsorption test were 54.8 µg/gr. With the RRF = 1 value indicating rock permeability after injection of polymer F1 2000 ppm, it tends not to experience plugging due to injection of polymer solution.
{"title":"Parameter Analysis of Polymer on Sandstone Reservoir in Indonesia: An Experimental Laboratory Study","authors":"G. S, B. Prasetiyo, T. Erfando","doi":"10.29017/scog.45.2.1185","DOIUrl":"https://doi.org/10.29017/scog.45.2.1185","url":null,"abstract":"Polymers are often used to increase oil recovery by improving sweeping efficiency. The screening was carried out as a first step in evaluating the test parameters of several polymers of the Hydrolyzed Polyacrylamide (HPAM) type in fluid and sandstone reservoir rocks. The test was carried out using a reservoir fluid classified as light oil (35°API) and at a reservoir temperature (60°C). The HPAM polymers used are A1, F1, F2, F3, and P1 polymers. The test parameters carried out on these 5 types of polymer (A1, F1, F2, F3 dan P1) include a compatibility test for formation water. The rheology polymer test includes concentration vs Tres, and shear rate vs viscosity which aims to determine the type of polymer solution being tested is a non-Newtonian or pseudoplastic fluid group. Thermal stability test of polymer for 60 days to determine the stability of the polymer solution and whether it is degraded or stable. Filtration testing with criteria FR value 1.2, screen factor test, and adsorption testing using the static method with a standard limit of adsorption value 400 µg/gr and polymer injectivity test. From these tests, scoring (range 0-100) was carried out to determine polymer candidates in polymer flooding testing. The F1 polymer candidate for the sandstone reservoir was obtained with a score of 82.25. From the scoring results, the selected F1 polymer candidate has a concentration value of 2000 ppm. For thermal degradation, the polymer F1 2000 ppm experienced degradation of 15.5%. The results of the F1 2000 ppm polymer static adsorption test were 54.8 µg/gr. With the RRF = 1 value indicating rock permeability after injection of polymer F1 2000 ppm, it tends not to experience plugging due to injection of polymer solution.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"27 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-01-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81088180","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}
Dadan Dsm Saputra, B. Prasetiyo, Hestuti Eni, Yudha Taufantri, Ghifahri Damara, Y. D. Rendragraha
The use of polymer solutions in the application of chemical EOR injection technology has a role in increasing oil recovery efforts by improving oil mobility in porous media. The addition of the polymer solution is expected to increase the viscosity value of the displacement fluid so that it can form a “piston-like” effect to increase the volumetric sweep efficiency of the light oil reservoir. The polymer used in this study was HPAM using 3 concentrations, namely 500 ppm, 1000 ppm, and 1500 ppm conducted at a temperature of 70 °C. The rheology test of the polymer included concentration vs temperature and shear rate vs viscosity. Thermal stability testing of polymer for 7, 14, 30, 60, and 90 days at 70 °C was done to determine the stability of the polymer solution. Filtration testing was conducted with the criteria of FR 1.2. The static adsorption test has been done with the standard limit of adsorption value 400 µg / gr. Polymer injectivity test using 3 variations of injection rates and coreflooding test were conducted to determine the reduction of Sor in reservoirs due to polymer displacement. From the polymer testing stage, it was found that HPAM polymers at 3 concentrations were compatible with the injection. This is indicated with the clear solution for 3 concentrations at room temperature and 70 °C. The rheology test results showed that the polymer solution with 3 concentrations was decreased in viscosity with the addition of the shear rate value. In the thermal stability test, the viscosity value of the HPAM with 500 ppm was relatively constant. The value of the FR for HPAM 500 ppm is 1.1, HPAM 1000 ppm is 1.07 and HPAM 1500 ppm is 1.03. The results of the static adsorption test showed the lowest HPAM value of 500 ppm was 156 µg/gr. In the injectivity test results, the resistance residual factor (RRF) values at injection rates of 0.3, 0.6, and 1 cc/min were 0.8, 1.04, and 1.12. The RRF value was close to 1, indicating that after injection of 500 ppm of HPAM tended to not experience plugging. Polymer flooding shows the oil recovery factor (RF) of water injection is 39% OOIP, and RF after polymer injection with 0.35 PV with flush water is 13.5% OOIP or 22% Sor. Knowing the behavior of HPAM polymer with various concentrations to be used for chemical EOR injection, it could provide advantages for future implementation in the light oil reservoir in Indonesia.
{"title":"Investigation of Polymer Flood Performance in Light Oil Reservoir: Laboratory Case Study","authors":"Dadan Dsm Saputra, B. Prasetiyo, Hestuti Eni, Yudha Taufantri, Ghifahri Damara, Y. D. Rendragraha","doi":"10.29017/scog.45.2.1181","DOIUrl":"https://doi.org/10.29017/scog.45.2.1181","url":null,"abstract":"The use of polymer solutions in the application of chemical EOR injection technology has a role in increasing oil recovery efforts by improving oil mobility in porous media. The addition of the polymer solution is expected to increase the viscosity value of the displacement fluid so that it can form a “piston-like” effect to increase the volumetric sweep efficiency of the light oil reservoir. The polymer used in this study was HPAM using 3 concentrations, namely 500 ppm, 1000 ppm, and 1500 ppm conducted at a temperature of 70 °C. The rheology test of the polymer included concentration vs temperature and shear rate vs viscosity. Thermal stability testing of polymer for 7, 14, 30, 60, and 90 days at 70 °C was done to determine the stability of the polymer solution. Filtration testing was conducted with the criteria of FR 1.2. The static adsorption test has been done with the standard limit of adsorption value 400 µg / gr. Polymer injectivity test using 3 variations of injection rates and coreflooding test were conducted to determine the reduction of Sor in reservoirs due to polymer displacement. From the polymer testing stage, it was found that HPAM polymers at 3 concentrations were compatible with the injection. This is indicated with the clear solution for 3 concentrations at room temperature and 70 °C. The rheology test results showed that the polymer solution with 3 concentrations was decreased in viscosity with the addition of the shear rate value. In the thermal stability test, the viscosity value of the HPAM with 500 ppm was relatively constant. The value of the FR for HPAM 500 ppm is 1.1, HPAM 1000 ppm is 1.07 and HPAM 1500 ppm is 1.03. The results of the static adsorption test showed the lowest HPAM value of 500 ppm was 156 µg/gr. In the injectivity test results, the resistance residual factor (RRF) values at injection rates of 0.3, 0.6, and 1 cc/min were 0.8, 1.04, and 1.12. The RRF value was close to 1, indicating that after injection of 500 ppm of HPAM tended to not experience plugging. Polymer flooding shows the oil recovery factor (RF) of water injection is 39% OOIP, and RF after polymer injection with 0.35 PV with flush water is 13.5% OOIP or 22% Sor. Knowing the behavior of HPAM polymer with various concentrations to be used for chemical EOR injection, it could provide advantages for future implementation in the light oil reservoir in Indonesia.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"21 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-01-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74450707","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}
Nurmajid Abdurrojaq, Rizal Zaelani, Belva Adam Haley, N. A. Fathurrahman, R. Anggarani, C. Wibowo, Maymuchar Maymuchar
Alcohol has the potential to be used as an alternative to fossil fuels to reduce total emissions from spark-ignition (SI) engines. The impact of a mixture of 20% methanol and ethanol in gasoline on the compatibility of Ethylene Propylene Diene Monomer (EPDM) and polyamide materials, which are used as fuel hoses in SI vehicles, is presented in this study. The immersion test methodology was employed to study the influence of both types of alcohol on gasoline blend to compatibility properties i.e., hardness and weight change. Based on the result, EPDM and polyamide materials have different characteristics of material compatibility with E20 and M20. Tests on M20 and E20 fuel samples on EPDM material show a higher effect on hardness by 5-9% than pristine gasoline. Additionally, there was no change in the weight of the polyamide material in the RON 90, E20, and M20 test samples. However, there was a change in the hardness of the polyamide material by 6-11% in RON 90, E20, and M20 fuels. Moreover, there was no change in the FTIR spectrum, indicating that there was no dissolution of the EPDM and polyamide materials into the test fuel for 6 weeks of immersion.
{"title":"The Effect of Methanol-Gasoline (M20) and Ethanol-Gasoline (E20) Blends on Material Compatibility","authors":"Nurmajid Abdurrojaq, Rizal Zaelani, Belva Adam Haley, N. A. Fathurrahman, R. Anggarani, C. Wibowo, Maymuchar Maymuchar","doi":"10.29017/scog.45.2.1183","DOIUrl":"https://doi.org/10.29017/scog.45.2.1183","url":null,"abstract":"Alcohol has the potential to be used as an alternative to fossil fuels to reduce total emissions from spark-ignition (SI) engines. The impact of a mixture of 20% methanol and ethanol in gasoline on the compatibility of Ethylene Propylene Diene Monomer (EPDM) and polyamide materials, which are used as fuel hoses in SI vehicles, is presented in this study. The immersion test methodology was employed to study the influence of both types of alcohol on gasoline blend to compatibility properties i.e., hardness and weight change. Based on the result, EPDM and polyamide materials have different characteristics of material compatibility with E20 and M20. Tests on M20 and E20 fuel samples on EPDM material show a higher effect on hardness by 5-9% than pristine gasoline. Additionally, there was no change in the weight of the polyamide material in the RON 90, E20, and M20 test samples. However, there was a change in the hardness of the polyamide material by 6-11% in RON 90, E20, and M20 fuels. Moreover, there was no change in the FTIR spectrum, indicating that there was no dissolution of the EPDM and polyamide materials into the test fuel for 6 weeks of immersion.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"2 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2023-01-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84279530","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}
Depletion of fossil fuel and increased pollution caused by the burning of fossil fuel is a leading factor in to use of alternate energy especially palm oil biodiesel as a mixture of diesel oil fuel (B-XX). It was reported that the use of the B-20 caused a blockage in the vehicle’s fuel filter. The blockage is caused by the presence of deposits formed from the agglomeration of monoglycerides. Three different biodiesels with monoglyceride content were used 0.40% - 0.60% by mass. The addition of monoglyceride standards (monopalmitin, monostearin, and monoolein) to biodiesel increases the volume of monoglyceride precipitates formed. The presence of these deposits decreases the flow properties of B-20. Research has been carried out to improve the flow properties of biodiesel by adding Sorbitan Monooleate (CMOST) surfactant, especially cloud points (CP) and cold filter plugging point (CFPP) parameters. The addition of 0.10%w - 1%w CMOST can reduce the CP by 4.80oC and CFPP by 2oC. This proves that the addition of SMO will improve the flow properties of B-XX as an alternative energy.
{"title":"Enhancement of Flow Properties Biodiesel Using Sorbitan Monooleate","authors":"Herlina Arina, M. Nasikin","doi":"10.29017/scog.45.3.1262","DOIUrl":"https://doi.org/10.29017/scog.45.3.1262","url":null,"abstract":"Depletion of fossil fuel and increased pollution caused by the burning of fossil fuel is a leading factor in to use of alternate energy especially palm oil biodiesel as a mixture of diesel oil fuel (B-XX). It was reported that the use of the B-20 caused a blockage in the vehicle’s fuel filter. The blockage is caused by the presence of deposits formed from the agglomeration of monoglycerides. Three different biodiesels with monoglyceride content were used 0.40% - 0.60% by mass. The addition of monoglyceride standards (monopalmitin, monostearin, and monoolein) to biodiesel increases the volume of monoglyceride precipitates formed. The presence of these deposits decreases the flow properties of B-20. Research has been carried out to improve the flow properties of biodiesel by adding Sorbitan Monooleate (CMOST) surfactant, especially cloud points (CP) and cold filter plugging point (CFPP) parameters. The addition of 0.10%w - 1%w CMOST can reduce the CP by 4.80oC and CFPP by 2oC. This proves that the addition of SMO will improve the flow properties of B-XX as an alternative energy.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"67 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81614600","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}
Ajeng P.P. Oktaviany, A. Dn, Utami Farahdibah, D. A. Maharsi, Wenny Astuti, M. Gibrata
This research aimed to obtain the petrophysical parameters of the capillary pressure of a sandstonefrom 3D modelling of high-resolution rock images. By integrating a number of 2D slice results, a plot of capillarypressure vs water saturation was built. When performing digital simulations using 512 x 512 x 512 pixels, theeffect on the resulting image was clearly seen using interactive thresholding. The obtained porosity was 29.5%while the permeability was obtained through iteration as 3942 mD, a quite large value since it is a synthetic core.Meanwhile, at the depth of free water level of 984 ft, the capillary pressure is found to be 167.36 psi with watersaturation at 4%.
本研究旨在通过高分辨率岩石图像的三维建模，获得砂岩毛管压力的岩石物理参数。通过对多个二维切片结果进行积分，建立了毛细管压力与含水饱和度的关系图。当使用512 x 512 x 512像素执行数字模拟时，使用交互式阈值可以清楚地看到对结果图像的影响。通过迭代得到的孔隙度为29.5%，渗透率为3942 mD，这是一个相当大的数值，因为它是一个合成岩心。同时，在自由水位984 ft处，毛细管压力为167.36 psi，含水饱和度为4%。
{"title":"Digital Core Analysis of Capillary Pressure in Sandstone","authors":"Ajeng P.P. Oktaviany, A. Dn, Utami Farahdibah, D. A. Maharsi, Wenny Astuti, M. Gibrata","doi":"10.29017/scog.45.3.1260","DOIUrl":"https://doi.org/10.29017/scog.45.3.1260","url":null,"abstract":"This research aimed to obtain the petrophysical parameters of the capillary pressure of a sandstonefrom 3D modelling of high-resolution rock images. By integrating a number of 2D slice results, a plot of capillarypressure vs water saturation was built. When performing digital simulations using 512 x 512 x 512 pixels, theeffect on the resulting image was clearly seen using interactive thresholding. The obtained porosity was 29.5%while the permeability was obtained through iteration as 3942 mD, a quite large value since it is a synthetic core.Meanwhile, at the depth of free water level of 984 ft, the capillary pressure is found to be 167.36 psi with watersaturation at 4%.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"64 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80881532","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}
Y. Sutadiwiria, Eko Bayu Purwasatriya, Cahyaningratri P R, D. Syavitri, M. Maulani, Asy’ari Alfin Giovany, Anjar Kurnia Ramadhan
Banyumas Basin is a basin that has signs of the presence of hydrocarbons, including oil and gasseep on the surface, which indicates active petroleum systems in the subsurface. A lot of oil and gas seeps werefound in Banyumas Basin, including oil seeps in Cipari and Besuki, while gas seeps were found in Mount Wetan,Karanglewas, and also Cipari. Exploration drilling wells have also been carried out, such as the Jati-1 Well, KarangNangka-1, Karang Gedang-1, Tjipari-1, and Mount Wetan-1, but there still has been no significant evidenceof this basin producing hydrocarbons. The TOC value of the outcrop samples taken in Cipari and Besuki have badvalues, while the crude oil has reflected a severe biodegradation process. Both oil seep samples and one extractbitumen contained high bicadinane (R (resin) annotation) and oleanane indicating both oils and extract to have aninput to Tertiary-sourced oils throughout Southeast Asia. Both oil seep samples do not exhibit similarity with theextract source rock. Based on this negative correlation there may be another source rocks in Banyumas Basin, derivedfrom rocks that are not only from Pemali Formation. The existence of this research is expected to be able toadd geological data, especially hydrocarbon geochemical data in Banyumas Basin, so that it can provide evidenceof the prospect and calculation of reserves contained in this basin, and an understanding of the source rock it self.
{"title":"Oil to Source Rock Correlation of Besuki Area and its Role in Petroleum System of Banyumas Basin","authors":"Y. Sutadiwiria, Eko Bayu Purwasatriya, Cahyaningratri P R, D. Syavitri, M. Maulani, Asy’ari Alfin Giovany, Anjar Kurnia Ramadhan","doi":"10.29017/scog.45.3.1256","DOIUrl":"https://doi.org/10.29017/scog.45.3.1256","url":null,"abstract":"Banyumas Basin is a basin that has signs of the presence of hydrocarbons, including oil and gasseep on the surface, which indicates active petroleum systems in the subsurface. A lot of oil and gas seeps werefound in Banyumas Basin, including oil seeps in Cipari and Besuki, while gas seeps were found in Mount Wetan,Karanglewas, and also Cipari. Exploration drilling wells have also been carried out, such as the Jati-1 Well, KarangNangka-1, Karang Gedang-1, Tjipari-1, and Mount Wetan-1, but there still has been no significant evidenceof this basin producing hydrocarbons. The TOC value of the outcrop samples taken in Cipari and Besuki have badvalues, while the crude oil has reflected a severe biodegradation process. Both oil seep samples and one extractbitumen contained high bicadinane (R (resin) annotation) and oleanane indicating both oils and extract to have aninput to Tertiary-sourced oils throughout Southeast Asia. Both oil seep samples do not exhibit similarity with theextract source rock. Based on this negative correlation there may be another source rocks in Banyumas Basin, derivedfrom rocks that are not only from Pemali Formation. The existence of this research is expected to be able toadd geological data, especially hydrocarbon geochemical data in Banyumas Basin, so that it can provide evidenceof the prospect and calculation of reserves contained in this basin, and an understanding of the source rock it self.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"11 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87347321","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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