Contact of surfactant solution onto rock surface has an important impact on the wettability alteration of the rock. This phenomenon has widely received attention of researchers on the field of EOR (enhanced oil recovery), at which surfactant solution basically has been used as the main injection fluid. However, there has not yet come up with conclusive findings, which is due to the unique characteristics of surfactant used at the oil fields. Therefore, every surfactant needs a particular laboratory evaluation before injected into a reservoir. We have evaluated surfactant-induced wettability alteration by means of contact angle measurement. Three kinds of surfactant have been used in this experiment, namely: TFSA (thin film spreading agent), IFT-R (interfacial tension reduction), and Well Stimulator type of surfactants. Two kinds of rocks namely LS (limestone) and SL (sandy limestone) have also been prepared. Both rocks are originally oil wet. TFSA-LS interaction tend to decrease the oil preferences with time, the contact angle increased 30 degrees after 8 weeks. Whereas TFSA-SL experienced only a little change of contact angle. Contact IFT-R and LS has changed significantly the contact angle to around 51degrees indicating less oil preference. Whereas, IFT-R and SL only changed a bit to less oil wet. The stimulator type of surfactant obviously lessen the oil wet tendency for the both rocks, the contact angles increase from initially around 15 to 35 degrees. In this experiment we found out that all the three surfactants generally tend to change the wettabillity to less oil wet.
{"title":"Surfactant-Induced Wettability Alteration","authors":"Sugihardjo Sugihardjo","doi":"10.29017/scog.32.1.834","DOIUrl":"https://doi.org/10.29017/scog.32.1.834","url":null,"abstract":"Contact of surfactant solution onto rock surface has an important impact on the wettability alteration of the rock. This phenomenon has widely received attention of researchers on the field of EOR (enhanced oil recovery), at which surfactant solution basically has been used as the main injection fluid. However, there has not yet come up with conclusive findings, which is due to the unique characteristics of surfactant used at the oil fields. Therefore, every surfactant needs a particular laboratory evaluation before injected into a reservoir. We have evaluated surfactant-induced wettability alteration by means of contact angle measurement. Three kinds of surfactant have been used in this experiment, namely: TFSA (thin film spreading agent), IFT-R (interfacial tension reduction), and Well Stimulator type of surfactants. Two kinds of rocks namely LS (limestone) and SL (sandy limestone) have also been prepared. Both rocks are originally oil wet. TFSA-LS interaction tend to decrease the oil preferences with time, the contact angle increased 30 degrees after 8 weeks. Whereas TFSA-SL experienced only a little change of contact angle. Contact IFT-R and LS has changed significantly the contact angle to around 51degrees indicating less oil preference. Whereas, IFT-R and SL only changed a bit to less oil wet. The stimulator type of surfactant obviously lessen the oil wet tendency for the both rocks, the contact angles increase from initially around 15 to 35 degrees. In this experiment we found out that all the three surfactants generally tend to change the wettabillity to less oil wet.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"64 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90447575","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}
Lithological complexity and intense hydrocarbon exploration with the objective of Late Miocene sediments in Kutei Basin has provided the impetus for more refined Late Miocene nannoplankton zonation than the standard global schemes of Martini (1971). Investigation to the quantitative nannoplankton analysis results in Kutei Basin has been done, and there is evident that the deltaic sediments of this basin give an excellent nannoplankton assemblage dataset to refine the Late Miocene biostratigraphy. Biostratigraphically, Late Miocene ranges from the middle part of zone NN9 to the middle part of zone NN12 of Martini zonation (1971). Zone NN11 is the most crucial zone to be refined since this zone has long time interval (more than 2m.a.). In this paper, this zone can be subdivided into 7 subzones (NN11a-NN11g) based on relatively permanent occurrences of 6 biomarkers. They are from the base to the top, as follow: FO Discoaster quinqueramus, LO. Minilitha convalis, LO Discoaster bergenii, FO Amaurolithus primus, FO Reticulofenestra rotaria, LO, Discoaster berggrenii, LO. Reticulofenestra rotaria and LO Discoaster quinqueramus. In spite of zone NN9, NN10 and NN12 which have relatively short stratigraphic ranges, each zone can also be subdivided into 2 subzones. The base and the top of zone NN9 is indicated respectively by the FO and LO Discoaster hamatus. It can be subdivided by the FO Discoaster prepentaradiatus into subzone NN9a and NN9b. Zone NN10 is marked by the LO Discoaster hamatus at the base and FO Discoaster quinqueramus at the top. It can be subdivided into subzones NN10a and NN10b by the LO Discoaster bollii. Zone NN12 is characterized by the LO Discoaster quinqueramus at the base and the FO Ceratolithus rugosus at the top. This zone can be subdivided into subzone NN12a and NN12b by the LO Helicosphaera intermedia.
{"title":"Revised Zonal Subdivision Of The Late Miocene Nannoplankton Biostratigraphy For Kutei Basin","authors":"Panuju Panuju","doi":"10.29017/scog.32.3.849","DOIUrl":"https://doi.org/10.29017/scog.32.3.849","url":null,"abstract":"Lithological complexity and intense hydrocarbon exploration with the objective of Late Miocene sediments in Kutei Basin has provided the impetus for more refined Late Miocene nannoplankton zonation than the standard global schemes of Martini (1971). Investigation to the quantitative nannoplankton analysis results in Kutei Basin has been done, and there is evident that the deltaic sediments of this basin give an excellent nannoplankton assemblage dataset to refine the Late Miocene biostratigraphy. Biostratigraphically, Late Miocene ranges from the middle part of zone NN9 to the middle part of zone NN12 of Martini zonation (1971). Zone NN11 is the most crucial zone to be refined since this zone has long time interval (more than 2m.a.). In this paper, this zone can be subdivided into 7 subzones (NN11a-NN11g) based on relatively permanent occurrences of 6 biomarkers. They are from the base to the top, as follow: FO Discoaster quinqueramus, LO. Minilitha convalis, LO Discoaster bergenii, FO Amaurolithus primus, FO Reticulofenestra rotaria, LO, Discoaster berggrenii, LO. Reticulofenestra rotaria and LO Discoaster quinqueramus. In spite of zone NN9, NN10 and NN12 which have relatively short stratigraphic ranges, each zone can also be subdivided into 2 subzones. The base and the top of zone NN9 is indicated respectively by the FO and LO Discoaster hamatus. It can be subdivided by the FO Discoaster prepentaradiatus into subzone NN9a and NN9b. Zone NN10 is marked by the LO Discoaster hamatus at the base and FO Discoaster quinqueramus at the top. It can be subdivided into subzones NN10a and NN10b by the LO Discoaster bollii. Zone NN12 is characterized by the LO Discoaster quinqueramus at the base and the FO Ceratolithus rugosus at the top. This zone can be subdivided into subzone NN12a and NN12b by the LO Helicosphaera intermedia.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"175 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77999464","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}
Spectral decomposition enables the resolution of seismic data to be improved significantly yielding a new possibility to map thin layers such channel sands and any other stratigraphic features. It has also been used in reservoir characterization. There are three methods for implementing spectral decomposition i.e., The Short Time Fourier Transform, the Continuous Wavelet Transform and the Matching Pursuit Decomposition. Among three of them, the Matching Pursuit Decomposition seems to be the most sophisticated one. It gives the best resolution among them. A simple and logical approach for explaining the spectral decomposition methods together with real data examples are presented in this paper by avoiding complex mathematical formulation.
{"title":"Spectral Decomposition Made Simple","authors":"S. Munadi, H. Purba","doi":"10.29017/scog.32.2.838","DOIUrl":"https://doi.org/10.29017/scog.32.2.838","url":null,"abstract":"Spectral decomposition enables the resolution of seismic data to be improved significantly yielding a new possibility to map thin layers such channel sands and any other stratigraphic features. It has also been used in reservoir characterization. There are three methods for implementing spectral decomposition i.e., The Short Time Fourier Transform, the Continuous Wavelet Transform and the Matching Pursuit Decomposition. Among three of them, the Matching Pursuit Decomposition seems to be the most sophisticated one. It gives the best resolution among them. A simple and logical approach for explaining the spectral decomposition methods together with real data examples are presented in this paper by avoiding complex mathematical formulation.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"18 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84966744","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}
Total global CO2 emissions from fossil-fuel will still increase in the next ten decades. These are attributed to the heavy reliance of human activities with fossil fuels. The uncontrolled CO2 emissions from combustion of fossil fuels cause the CO2 concentration alteration in the atmosphere. As the result, this phenomenon cause global warming and change the climate globally. In the future, CO2 emissions are predicted in range from 29 to 44 GtCO2/year in 2020. Therefore it is necessary to abate the CO2 missions to the level that would prevent dangerous anthropogenic interference to the global climate system. The growth of energy efficiency improvements, the switch to less-carbon intensive fuels and renewable resources employment is still low in the context CO2 emissions mitigation. Carbon Dioxide Capture and Storage (CCS) as a third option for these mitigation options might facilitate achieving CO2 missions stabilization goals. As a part of the commitment and participation on combating the global warming, Indonesia has signed the Kyoto Protocol in 1998 and ratified it in 2004 through Law No. 17/2004. On the other side, Indonesia oil production has been declining since in the last ten years but demand for this energy is still high. In this frame CCS-Enhanced Oil Recovery (EOR) by CO2 injection might answer the global warming challenges and alongside contribute to increase the oil production in the near future. This paper presents a preliminary study of CCS-EOR potential in Indonesia. A brief explanation of geological setting and reservoir screening for site selection also presented. Then some discussions about CCS-EOR global potential will be highlighted as well as the analysis. It is hoped that this study would provide a standard guideline for determining CCS- EOR potential in Indonesia.
{"title":"Carbon Capture And Storage (Ccs) - Enhanced Oil Recovery (Eor): Global Potential In Indonesia","authors":"U. Iskandar, E. Syahrial","doi":"10.29017/scog.32.3.855","DOIUrl":"https://doi.org/10.29017/scog.32.3.855","url":null,"abstract":"Total global CO2 emissions from fossil-fuel will still increase in the next ten decades. These are attributed to the heavy reliance of human activities with fossil fuels. The uncontrolled CO2 emissions from combustion of fossil fuels cause the CO2 concentration alteration in the atmosphere. As the result, this phenomenon cause global warming and change the climate globally. In the future, CO2 emissions are predicted in range from 29 to 44 GtCO2/year in 2020. Therefore it is necessary to abate the CO2 missions to the level that would prevent dangerous anthropogenic interference to the global climate system. The growth of energy efficiency improvements, the switch to less-carbon intensive fuels and renewable resources employment is still low in the context CO2 emissions mitigation. Carbon Dioxide Capture and Storage (CCS) as a third option for these mitigation options might facilitate achieving CO2 missions stabilization goals. As a part of the commitment and participation on combating the global warming, Indonesia has signed the Kyoto Protocol in 1998 and ratified it in 2004 through Law No. 17/2004. On the other side, Indonesia oil production has been declining since in the last ten years but demand for this energy is still high. In this frame CCS-Enhanced Oil Recovery (EOR) by CO2 injection might answer the global warming challenges and alongside contribute to increase the oil production in the near future. This paper presents a preliminary study of CCS-EOR potential in Indonesia. A brief explanation of geological setting and reservoir screening for site selection also presented. Then some discussions about CCS-EOR global potential will be highlighted as well as the analysis. It is hoped that this study would provide a standard guideline for determining CCS- EOR potential in Indonesia.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"6 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80451684","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}
All analyzed crude oil samples contain firstly, the carbon contents in a range of 75.2830 % wt – 83.5739 % wt. Secondly, asphalthene with in a range of 0.6930 % wt – 1.8260 % wt and it can deposit in the formation and block the pore throats, which may reduce the permeability significantly. Thirdly, the hydrogen contents in a range of 9.1948 % wt –11.2339 % wt and it is impurities crude oil indicator. Fourthly, the crude oil samples have zero % wt nitrogen contents and don’t result in corrosive properties. However, the existence of the oxygen contents (in a range of 5.1634 % wt – 14.0560 % wt) and the sulfur contents (in a range of 0.1334 % wt – 0.2533 % wt) in the crude oil samples may cause corrosion problem.
{"title":"Determination Of Asphaltene And C, H, N, O, S Contents In Crude Oil From X-Oilfield In South Sumatra","authors":"Tjuwati Makmur","doi":"10.29017/scog.32.2.840","DOIUrl":"https://doi.org/10.29017/scog.32.2.840","url":null,"abstract":"All analyzed crude oil samples contain firstly, the carbon contents in a range of 75.2830 % wt – 83.5739 % wt. Secondly, asphalthene with in a range of 0.6930 % wt – 1.8260 % wt and it can deposit in the formation and block the pore throats, which may reduce the permeability significantly. Thirdly, the hydrogen contents in a range of 9.1948 % wt –11.2339 % wt and it is impurities crude oil indicator. Fourthly, the crude oil samples have zero % wt nitrogen contents and don’t result in corrosive properties. However, the existence of the oxygen contents (in a range of 5.1634 % wt – 14.0560 % wt) and the sulfur contents (in a range of 0.1334 % wt – 0.2533 % wt) in the crude oil samples may cause corrosion problem.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"30 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84972314","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}
Micro-algae are plant like organisms belong to Thallophytic group, they have no true roots, stems, and leaves. They can easy to grow in fresh, saline, and brackish water. Like plants, micro-algae can conduct photosynthetic process to manufacture carbohydrates for their own food. Algal cell generally contains high concentration of proteins, carbohydrates, and lipids. Micro-algae grow very rapidly, and their biomass is commonly double within 24 hours. The algal are the highest potential energy yield agricultural oil crop. In accordance with capability of their lives, micro-algae have potential as feedstuff for alternative energy. Other capabilities of algal are as carbon dioxide reduction, animal feed, livestock feed, fertilizer, supplement for human health, etc.
{"title":"The Superiority Of Micro-Algae As A Potential Feedstock For Alternative Energy","authors":"M. Udiharto, Rino Nirwawan, S. Rahayu","doi":"10.29017/scog.32.1.829","DOIUrl":"https://doi.org/10.29017/scog.32.1.829","url":null,"abstract":"Micro-algae are plant like organisms belong to Thallophytic group, they have no true roots, stems, and leaves. They can easy to grow in fresh, saline, and brackish water. Like plants, micro-algae can conduct photosynthetic process to manufacture carbohydrates for their own food. Algal cell generally contains high concentration of proteins, carbohydrates, and lipids. Micro-algae grow very rapidly, and their biomass is commonly double within 24 hours. The algal are the highest potential energy yield agricultural oil crop. In accordance with capability of their lives, micro-algae have potential as feedstuff for alternative energy. Other capabilities of algal are as carbon dioxide reduction, animal feed, livestock feed, fertilizer, supplement for human health, etc.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"14 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81774158","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}
One of most problems occur in oil production equipments is corrosion that is caused by some factors, such as the existence of sulfate reducing bacteria and dissolved oxygen in injection water. Based on the results of laboratory, A–GS and R–GS contain 0.90 ppm and 1.19 ppm dissolved oxygen and have potential to form corrosion problem, except D–GS with 0 ppm dissolved oxygen and no corrosion problem. After SRB tests, A–GS tube appearance colour is not black, because SRB is not found in the A–GS injection water. Whereas, R–GS and D–GS contain SRB with sulfate reducers 100,000, therefore R–GS and D–GS tubes appearance colour are completely black
{"title":"The Occurrence Of Corrosion Problem In Oil Production Equipment Caused By Sulfate Reducing Bacteria And Dissolved Oxygen","authors":"N. Nuraini, Febrianto Febrianto","doi":"10.29017/scog.32.2.845","DOIUrl":"https://doi.org/10.29017/scog.32.2.845","url":null,"abstract":"One of most problems occur in oil production equipments is corrosion that is caused by some factors, such as the existence of sulfate reducing bacteria and dissolved oxygen in injection water. Based on the results of laboratory, A–GS and R–GS contain 0.90 ppm and 1.19 ppm dissolved oxygen and have potential to form corrosion problem, except D–GS with 0 ppm dissolved oxygen and no corrosion problem. After SRB tests, A–GS tube appearance colour is not black, because SRB is not found in the A–GS injection water. Whereas, R–GS and D–GS contain SRB with sulfate reducers 100,000, therefore R–GS and D–GS tubes appearance colour are completely black","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"27 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89378653","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}
Coal Bed Methane pilot project has produced around 80 m3 CBM gas containing around 14,66% volume of CO2 and 85,34% volume of CH4. CO2 has to be removed, the methane gas can be utilized to produce residential electricity applying the lattest technology. Some equipment need to be installed in place at proposed CBM gas site plant to produce the electricity of around 150 KWe per day or 51,75 MWe per annum from which the pilot project can be scaled up to 1 x 55 MW gas fuelled power plant.
煤层气试点项目已生产出约80立方米的煤层气，其中CO2含量约为14.66%，CH4含量约为85.34%。二氧化碳必须去除，甲烷气体可以利用最新技术生产住宅电力。在拟议的煤层气天然气发电厂需要安装一些设备，以产生每天约150千瓦时或每年51,75兆瓦的电力，由此试点项目可以扩大到1 x 55兆瓦的天然气发电厂。
{"title":"Developing Coal Bed Methane Gas Utilization Pilot Project To Produce Residential Electricity","authors":"Y. K. Caryana","doi":"10.29017/scog.32.3.852","DOIUrl":"https://doi.org/10.29017/scog.32.3.852","url":null,"abstract":"Coal Bed Methane pilot project has produced around 80 m3 CBM gas containing around 14,66% volume of CO2 and 85,34% volume of CH4. CO2 has to be removed, the methane gas can be utilized to produce residential electricity applying the lattest technology. Some equipment need to be installed in place at proposed CBM gas site plant to produce the electricity of around 150 KWe per day or 51,75 MWe per annum from which the pilot project can be scaled up to 1 x 55 MW gas fuelled power plant.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"3 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78226891","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 effect of delayed evaporation rate on CO2/CH4 selectivity was investigated on cellulose acetate based membrane in composition of cellulose acetate and acetone (CA+ACE), cellulose acetate, acetone and formamide (CA+ACE+F) and cellulose acetate, acetone, formamide and polyethylene glycol 400 (CA+ACE+F+PEG). Delayed evaporation was carried out in acetone saturated air. The study shows that the presence of PEG in membrane composition gives a probability for the membrane to be used and kept in dry state. Evaporation time at standard evaporation rate for membrane composition CA+ACE+F andd CA+ACE+F+PEG to get better selectivity is not less than 60 seconds. SEM shows that macrovoids in membrane prepared by delayed evaporation rate compared to those prepared by standard evaporation are smaller in size but higher in numbers.Effects of 60 seconds of delayed evaporation rate on membrane selectivity and permeability is about the same with the effects of 15 seconds of standard evaporation. It brought abourt, in turn, a thought, that the effects of 8 seconds evaporation in spineret on hollow fibre selectivity and permeability can be increased by increasing evaporation rate.
{"title":"Effects Of Delayed Evaporation In Cellulose Acetate Membrane Preparation To Separate Co2/Ch4 At Low Pressure","authors":"Adiwar Adiwar","doi":"10.29017/scog.32.3.847","DOIUrl":"https://doi.org/10.29017/scog.32.3.847","url":null,"abstract":"The effect of delayed evaporation rate on CO2/CH4 selectivity was investigated on cellulose acetate based membrane in composition of cellulose acetate and acetone (CA+ACE), cellulose acetate, acetone and formamide (CA+ACE+F) and cellulose acetate, acetone, formamide and polyethylene glycol 400 (CA+ACE+F+PEG). Delayed evaporation was carried out in acetone saturated air. The study shows that the presence of PEG in membrane composition gives a probability for the membrane to be used and kept in dry state. Evaporation time at standard evaporation rate for membrane composition CA+ACE+F andd CA+ACE+F+PEG to get better selectivity is not less than 60 seconds. SEM shows that macrovoids in membrane prepared by delayed evaporation rate compared to those prepared by standard evaporation are smaller in size but higher in numbers.Effects of 60 seconds of delayed evaporation rate on membrane selectivity and permeability is about the same with the effects of 15 seconds of standard evaporation. It brought abourt, in turn, a thought, that the effects of 8 seconds evaporation in spineret on hollow fibre selectivity and permeability can be increased by increasing evaporation rate.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"349 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79730977","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 sonic log enables all features along the depth scale can be correlated with all features in the ime scale as found in the seismic section. However, this sonic log must beThe sonic log enables all atures along the depth scale can be correlated with all features in the time scale as found in the seismic section. However, this sonic log must be corrected to the time-depth curve obtained from the check shot survey. The problem arises when some zones around the borehole such as the invaded zones or the flushed zones exhibit dispersive properties. This dispersive properties causes discrepancies between integrated sonic transit time and the time-depth curve. As a result, the synthetic seismogram generated from the sonic log will not match with the corresponding seismic section. To solve this problem, a practical method for correcting the discrepancies is presented in this paper. Although the method is inspired by paper published in the seventies, but the way to approach the problem is different. This problem looks simple, but its effect on mapping top and bottom of the reservoir is important. An example of implementation from the real field is also given. corrected to the time-depth curve obtained from the check shot survey. The problem arises when some zones around the borehole such as the invaded zones or the flushed zones exhibit dispersive properties. This dispersive properties causes discrepancies between integrated sonic transit time and the time-depth curve. As a result, the synthetic seismogram generated from the sonic log will not match with the corresponding seismic section. To solve this problem, a practical method for correcting the discrepancies is presented in this paper. Although the method is inspired by paper published in the seventies, but the way to approach the problem is different. This problem looks simple, but its effect on mapping top and bottom of the reservoir is important. An example of implementation from the real field is also given.
{"title":"Seismic Versus Sonic Revisited","authors":"S. Munadi","doi":"10.29017/scog.32.1.826","DOIUrl":"https://doi.org/10.29017/scog.32.1.826","url":null,"abstract":"The sonic log enables all features along the depth scale can be correlated with all features in the ime scale as found in the seismic section. However, this sonic log must beThe sonic log enables all atures along the depth scale can be correlated with all features in the time scale as found in the seismic section. However, this sonic log must be corrected to the time-depth curve obtained from the check shot survey. The problem arises when some zones around the borehole such as the invaded zones or the flushed zones exhibit dispersive properties. This dispersive properties causes discrepancies between integrated sonic transit time and the time-depth curve. As a result, the synthetic seismogram generated from the sonic log will not match with the corresponding seismic section. To solve this problem, a practical method for correcting the discrepancies is presented in this paper. Although the method is inspired by paper published in the seventies, but the way to approach the problem is different. This problem looks simple, but its effect on mapping top and bottom of the reservoir is important. An example of implementation from the real field is also given. corrected to the time-depth curve obtained from the check shot survey. The problem arises when some zones around the borehole such as the invaded zones or the flushed zones exhibit dispersive properties. This dispersive properties causes discrepancies between integrated sonic transit time and the time-depth curve. As a result, the synthetic seismogram generated from the sonic log will not match with the corresponding seismic section. To solve this problem, a practical method for correcting the discrepancies is presented in this paper. Although the method is inspired by paper published in the seventies, but the way to approach the problem is different. This problem looks simple, but its effect on mapping top and bottom of the reservoir is important. An example of implementation from the real field is also given.","PeriodicalId":21649,"journal":{"name":"Scientific Contributions Oil and Gas","volume":"86 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88410949","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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