Optimum drilling penetration rate, known as the rate of penetration (ROP) has played a big role in drilling operations. Planning the well ROP always becomes a challenge for drilling engineers to calculate the drilling time needed for the section. Optimum ROP is achieved when the time to drill the section is as planned. Many empirical approaches were develop to model the ROP based on the drilling parameters, and might not always match the actual ROP. In some cases, the actual ROP was slower than planned, which may increase the drilling cost, which needs to be avoided. Hence, some approaches using artificial intelligent (AI), and supervised machine learning have been develop to overcome it. Supervised machine learning is used to develop a ROP model and ROP prediction for one of the development fields, based only on two wells drilling parameters data. The model was train using Gradient Boosting, Random Forest, and Support Vector Machine. Drilling parameter test data then is used to validate the model. The model of Random Forest shows a good or promising result with R2 of 0.90, Gradient Boosting shows R2 of 0.86, and Support Vector Machine with R2 0.72. Based on the models generated, the Random Forest has shown good trend which could be used for modeling ROP in the future development wells.
{"title":"ROP Prediction with Supervised Machine Learning; a Case Study","authors":"G. R. Darmawan, D. Irawan","doi":"10.25299/jeee.2022.7772","DOIUrl":"https://doi.org/10.25299/jeee.2022.7772","url":null,"abstract":"Optimum drilling penetration rate, known as the rate of penetration (ROP) has played a big role in drilling operations. Planning the well ROP always becomes a challenge for drilling engineers to calculate the drilling time needed for the section. Optimum ROP is achieved when the time to drill the section is as planned. \u0000Many empirical approaches were develop to model the ROP based on the drilling parameters, and might not always match the actual ROP. In some cases, the actual ROP was slower than planned, which may increase the drilling cost, which needs to be avoided. \u0000Hence, some approaches using artificial intelligent (AI), and supervised machine learning have been develop to overcome it. Supervised machine learning is used to develop a ROP model and ROP prediction for one of the development fields, based only on two wells drilling parameters data. The model was train using Gradient Boosting, Random Forest, and Support Vector Machine. Drilling parameter test data then is used to validate the model. The model of Random Forest shows a good or promising result with R2 of 0.90, Gradient Boosting shows R2 of 0.86, and Support Vector Machine with R2 0.72. Based on the models generated, the Random Forest has shown good trend which could be used for modeling ROP in the future development wells.","PeriodicalId":33635,"journal":{"name":"Journal of Earth Energy Engineering","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2022-05-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"45903884","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 “CJ” field is a gas field located in the South Sumatra Basin with a reservoir located in the Basalt Telisa Limestone (BTL) formation. This gas field consists of 3 wells namely Well GTA-1, GTA-2, and GTA-3 which produced from 1951 to 1991. In 1991 the three wells were suspended and will be reopened in 2021 due to requests from buyers for 10 years. The research method used is to collect data consisting of data on reservoir, production, and physical properties of the gas. The next step is to calculate the value of the gas formation volume factor and Z-factor with various pressures. Next, determine the type of drive mechanism using the Cole Plot method. After knowing the type of drive mechanism, you can determine the current OGIP value using the material balance method. If the OGIP value is known, the next calculation is the Recovery Factor (RF), Ultimate Recovery (UR) and finally the value of Remaining Reserve (RR). Based on the calculation, the current OGIP value obtained by the material balance method with P / Z vs GP plots is 83.46 BSCF, Recovery Factor of 80.223%, Ultimate Recovery of 66.96 BSCF, and remaining gas reserve 15.45 BSCF. From these results, the maximum reserve value that can be produced to the surface for 10 years is 4.2325 MMSCFD. So that "CJ" Field is able to supply gas every day of 4.2325 MMSCFD or less than 4.2325 MMSCFD for 10 years.
{"title":"Evaluation of Remaining Gas Reserves Using the Material Balance Method for Planning Gas Field Development","authors":"D. Ratnaningsih, A. M. Suranto, Cahyadi Julianto","doi":"10.25299/jeee.2022.6632","DOIUrl":"https://doi.org/10.25299/jeee.2022.6632","url":null,"abstract":"The “CJ” field is a gas field located in the South Sumatra Basin with a reservoir located in the Basalt Telisa Limestone (BTL) formation. This gas field consists of 3 wells namely Well GTA-1, GTA-2, and GTA-3 which produced from 1951 to 1991. In 1991 the three wells were suspended and will be reopened in 2021 due to requests from buyers for 10 years. The research method used is to collect data consisting of data on reservoir, production, and physical properties of the gas. The next step is to calculate the value of the gas formation volume factor and Z-factor with various pressures. Next, determine the type of drive mechanism using the Cole Plot method. After knowing the type of drive mechanism, you can determine the current OGIP value using the material balance method. If the OGIP value is known, the next calculation is the Recovery Factor (RF), Ultimate Recovery (UR) and finally the value of Remaining Reserve (RR). Based on the calculation, the current OGIP value obtained by the material balance method with P / Z vs GP plots is 83.46 BSCF, Recovery Factor of 80.223%, Ultimate Recovery of 66.96 BSCF, and remaining gas reserve 15.45 BSCF. From these results, the maximum reserve value that can be produced to the surface for 10 years is 4.2325 MMSCFD. So that \"CJ\" Field is able to supply gas every day of 4.2325 MMSCFD or less than 4.2325 MMSCFD for 10 years.","PeriodicalId":33635,"journal":{"name":"Journal of Earth Energy Engineering","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2022-05-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"42078175","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}
Recently, Indonesia will lead to gas deficits since the increase in domestic gas demand in 2040. The increasing need for energy sources and the decreasing available reserves have encouraged oil and gas companies to explore and manage marginal reservoirs such as sour gas environment to maintain the balance of energy supply and demand. The gap in gas supply-demand will decrease by 20% due to the supply of Natuna Gas Field, as the example of potential sour gas environment (Batubara, 2015). Thus, it is very relevant to develop this potential source immediately. Also, sour gas field approximately shares 40% of Indonesia’s total proven gas reserve with an estimated OGIP of around 222 TSCF, with 75% of gas recovery. Unfortunately, sour gas environment cannot be produced economically since the it has high carbon dioxide (CO2) and hydrogen sulfide (H2S) content, which are toxic and corrosive. The X sour reserves contain 32% carbon dioxide (CO2) and 7072 ppm H2S with fluid gravity of 42 API. This discretionary source of CO2 was recently brought into production from one well with depth of 8400 ft. The well was perforated in a limited interval of 7100 until 7700 ft. The harsh environment presented many challenges to completion design. Unique equipment and material selection were required. This study aims to determine the reservoir fluids and production performance also predict the corrosivity of CO2 dissolved in the natural gas. With the simulation and prediction, it can be obtained the proper material and equipment selection based on the sour service needed. As a result, the wet gas reservoir of X field can produce optimum rate of 19.1063 MMSCFD. For completion design, Nickel Alloy SM2535 or SM2242 is needed as there will be damage in form of corrosion and pitting.
{"title":"INTEGRATED COMPLETION STUDY FOR HPHT SOUR GAS WELL DEVELOPMENT IN CARBONATE RESERVOIR X","authors":"S. Chandra, Wijoyo Niti Daton, Ellen Setiawan","doi":"10.25299/jeee.2022.7133","DOIUrl":"https://doi.org/10.25299/jeee.2022.7133","url":null,"abstract":"Recently, Indonesia will lead to gas deficits since the increase in domestic gas demand in 2040. The increasing need for energy sources and the decreasing available reserves have encouraged oil and gas companies to explore and manage marginal reservoirs such as sour gas environment to maintain the balance of energy supply and demand. The gap in gas supply-demand will decrease by 20% due to the supply of Natuna Gas Field, as the example of potential sour gas environment (Batubara, 2015). Thus, it is very relevant to develop this potential source immediately. \u0000Also, sour gas field approximately shares 40% of Indonesia’s total proven gas reserve with an estimated OGIP of around 222 TSCF, with 75% of gas recovery. Unfortunately, sour gas environment cannot be produced economically since the it has high carbon dioxide (CO2) and hydrogen sulfide (H2S) content, which are toxic and corrosive. \u0000The X sour reserves contain 32% carbon dioxide (CO2) and 7072 ppm H2S with fluid gravity of 42 API. This discretionary source of CO2 was recently brought into production from one well with depth of 8400 ft. The well was perforated in a limited interval of 7100 until 7700 ft. The harsh environment presented many challenges to completion design. Unique equipment and material selection were required. \u0000This study aims to determine the reservoir fluids and production performance also predict the corrosivity of CO2 dissolved in the natural gas. With the simulation and prediction, it can be obtained the proper material and equipment selection based on the sour service needed. As a result, the wet gas reservoir of X field can produce optimum rate of 19.1063 MMSCFD. For completion design, Nickel Alloy SM2535 or SM2242 is needed as there will be damage in form of corrosion and pitting.","PeriodicalId":33635,"journal":{"name":"Journal of Earth Energy Engineering","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2022-05-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"43881078","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}
B. Swadesi, Roiduz Zumar, Sinosa Husenido, D. Kristanto, Indah Widiyaningsih, S. Murni
Polymer injection is one method of chemical enhanced oil recovery, which increase oil recovery by improving mobility when viscous fingering occurred in waterflooding operation. The result of polymer injection is better sweep efficiency, which is presented by more even distribution of the injected fluid. However, in common laboratory evaluation for polymer injection testing, it was no visual observation that presents directly for the fluid distribution. This experimental study was carried out to visually observe the polymer injection mechanism to displace oil by micromodel as porous media. The micromodel used in this study is transparent acrylic material which was etched by laser engraving technology to create grains that resemble reservoir rocks. The micromodel was saturated by brine water and light oil respectively as initial reservoir fluids. Then, the water was injected as waterflooding operation to displace oil in a micromodel. Hydrolyzed Polyacrylamide (HPAM) polymer with various concentrations were injected into the micromodel as the last scenario. Through this experiment, the movement and distribution of fluids in chemical enhanced oil recovery especially polymer injection was able to be recorded for further analysis. Observation for each scenario was done by Digital Image Analysis (DIA). The micromodel flooding results showed that the higher concentration of polymer would give higher oil recovery. The front stability and good distribution of polymer will result in better sweep efficiency, then higher oil recovery will be achieved. This experiment gives result visually how polymer enhance oil recovery. This experiment is expected to be leading innovation for Enhanced Oil Recovery (EOR) laboratory studies in Indonesia.
{"title":"Experimental Study of Polymer Injection on Oil Recovery Factor Enhancement Using Homogenous and Heterogenous Micromodel Porous Media","authors":"B. Swadesi, Roiduz Zumar, Sinosa Husenido, D. Kristanto, Indah Widiyaningsih, S. Murni","doi":"10.25299/jeee.2022.6791","DOIUrl":"https://doi.org/10.25299/jeee.2022.6791","url":null,"abstract":"Polymer injection is one method of chemical enhanced oil recovery, which increase oil recovery by improving mobility when viscous fingering occurred in waterflooding operation. The result of polymer injection is better sweep efficiency, which is presented by more even distribution of the injected fluid. However, in common laboratory evaluation for polymer injection testing, it was no visual observation that presents directly for the fluid distribution. This experimental study was carried out to visually observe the polymer injection mechanism to displace oil by micromodel as porous media. The micromodel used in this study is transparent acrylic material which was etched by laser engraving technology to create grains that resemble reservoir rocks. The micromodel was saturated by brine water and light oil respectively as initial reservoir fluids. Then, the water was injected as waterflooding operation to displace oil in a micromodel. Hydrolyzed Polyacrylamide (HPAM) polymer with various concentrations were injected into the micromodel as the last scenario. Through this experiment, the movement and distribution of fluids in chemical enhanced oil recovery especially polymer injection was able to be recorded for further analysis. Observation for each scenario was done by Digital Image Analysis (DIA). The micromodel flooding results showed that the higher concentration of polymer would give higher oil recovery. The front stability and good distribution of polymer will result in better sweep efficiency, then higher oil recovery will be achieved. This experiment gives result visually how polymer enhance oil recovery. This experiment is expected to be leading innovation for Enhanced Oil Recovery (EOR) laboratory studies in Indonesia.","PeriodicalId":33635,"journal":{"name":"Journal of Earth Energy Engineering","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2022-05-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"43209605","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}
Bright Bariakpoa Kinate, A. Nwosi-Anele, I. Nwankwo
Hydrocarbon production from underneath naturally fractured sandstone formations will reach a mature phase of production where natural pressure can no longer force fluids to the surface facilities, therefore, a cost-effective enhanced oil recovery (EOR) approach is required to recover the remaining oil. Water alternated gas(WAG) injection is a promising EOR method that utilize the combine advantage of water and gas injection to achieve better mobility control, improved sweep efficiency and overall recovery from the given reservoir. In this study, a miscible WAG to a core flood model using numerical simulation techniques (Eclipse Reservoir Simulator – Black Oil Model Option) was investigated. A case study reservoir X was produced for 15 years using three wells after initial forecast showed that natural depletion could not sustain production from the earliest time of production. With different simulation scenarios that represent specific case of WAG ratio, optimal WAG ratio using oil recovery factor was selected and used to perform twelve (12) simulation runs to ascertain the influence of WAG cycle period on oil recovery factor. The most effective WAG cycle scenario was 90W-30G with oil recovery factor of 0.54684 (54.68 %) and cumulative production of 14.987MMSTB, while 30W-90G gives the lowest oil recovery factor and cumulative production of 0.47468 (47.47%) and 12.996MMSTB respectively. Hence, higher water cycling period is required for better oil recovery. Also, lower water to gas injection rates (WAG ratio) enhances the recovery of oil from the reservoir. Results reveals that despite predicted higher recovery factor, lower WAG ratio showed a potential of relatively poor pressure maintenance which can impact future recovery from the reservoir
{"title":"Evaluation of the use of Water Alternated Gas Injection for Enhanced Oil Recovery","authors":"Bright Bariakpoa Kinate, A. Nwosi-Anele, I. Nwankwo","doi":"10.25299/jeee.2022.7410","DOIUrl":"https://doi.org/10.25299/jeee.2022.7410","url":null,"abstract":"Hydrocarbon production from underneath naturally fractured sandstone formations will reach a mature phase of production where natural pressure can no longer force fluids to the surface facilities, therefore, a cost-effective enhanced oil recovery (EOR) approach is required to recover the remaining oil. Water alternated gas(WAG) injection is a promising EOR method that utilize the combine advantage of water and gas injection to achieve better mobility control, improved sweep efficiency and overall recovery from the given reservoir. In this study, a miscible WAG to a core flood model using numerical simulation techniques (Eclipse Reservoir Simulator – Black Oil Model Option) was investigated. A case study reservoir X was produced for 15 years using three wells after initial forecast showed that natural depletion could not sustain production from the earliest time of production. With different simulation scenarios that represent specific case of WAG ratio, optimal WAG ratio using oil recovery factor was selected and used to perform twelve (12) simulation runs to ascertain the influence of WAG cycle period on oil recovery factor. The most effective WAG cycle scenario was 90W-30G with oil recovery factor of 0.54684 (54.68 %) and cumulative production of 14.987MMSTB, while 30W-90G gives the lowest oil recovery factor and cumulative production of 0.47468 (47.47%) and 12.996MMSTB respectively. Hence, higher water cycling period is required for better oil recovery. Also, lower water to gas injection rates (WAG ratio) enhances the recovery of oil from the reservoir. Results reveals that despite predicted higher recovery factor, lower WAG ratio showed a potential of relatively poor pressure maintenance which can impact future recovery from the reservoir","PeriodicalId":33635,"journal":{"name":"Journal of Earth Energy Engineering","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2022-05-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"47144547","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}
Drillstrings often vibrate severely and tend to twist off during hard rock drilling. Therefore, dynamic testing is crucial in the design of drilling systems. Designers tend to employ the most powerful analytical tools, using the most elaborate electronic computers, however, actual testing is required to the designed system function optimally. In cases of enormous drilling systems, complex dynamic tests are often performed on a smaller-scale replica of the system, referred to as the model, which is more convenient, cost-effective, and time-effective. This study, therefore, describes the establishment of similar conditions among structural systems, with the main objective of studying the similitude theory’s applicability in establishing the necessary similar conditions for designing scaled-down models to predict the drillstring’s vibration behavior. The scaling laws for all the relevant parameters regarding the scaled drillstring model, as well as the full-size drillstring system, were derived from the respective equations of motion. The scaling factors for all relevant parameters are determined using the theory of dimensional analysis. In addition, the geometry distorted similitude theory is revisited and employed to overcome the physical limitation and develop the necessary similar conditions for dynamic testing of the scaled drillstring. Meanwhile, the similitude relationship between the prototype and the model was validated with a case study using lumped segments bond graph modeling and simulation software.
{"title":"A Study of The Design Method and Similitude for A Small-Scale Test Drilling Rig (Part 1): An Application of The Geometrically Distorted Scaled Modeling Method","authors":"M. Sarker","doi":"10.25299/jeee.2021.7466","DOIUrl":"https://doi.org/10.25299/jeee.2021.7466","url":null,"abstract":"Drillstrings often vibrate severely and tend to twist off during hard rock drilling. Therefore, dynamic testing is crucial in the design of drilling systems. Designers tend to employ the most powerful analytical tools, using the most elaborate electronic computers, however, actual testing is required to the designed system function optimally. In cases of enormous drilling systems, complex dynamic tests are often performed on a smaller-scale replica of the system, referred to as the model, which is more convenient, cost-effective, and time-effective. This study, therefore, describes the establishment of similar conditions among structural systems, with the main objective of studying the similitude theory’s applicability in establishing the necessary similar conditions for designing scaled-down models to predict the drillstring’s vibration behavior. The scaling laws for all the relevant parameters regarding the scaled drillstring model, as well as the full-size drillstring system, were derived from the respective equations of motion. The scaling factors for all relevant parameters are determined using the theory of dimensional analysis. In addition, the geometry distorted similitude theory is revisited and employed to overcome the physical limitation and develop the necessary similar conditions for dynamic testing of the scaled drillstring. Meanwhile, the similitude relationship between the prototype and the model was validated with a case study using lumped segments bond graph modeling and simulation software.","PeriodicalId":33635,"journal":{"name":"Journal of Earth Energy Engineering","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-11-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"48827397","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}
In the gas well, liquid loading occurs when the gas rate is insufficient to lift liquids into the surface such as water and/or condensate. This causes an accumulation of the liquid in the wellbore, supplies additional backpressure to the formation, and may completely kill the well. Meanwhile, the limited space and typically high cost of offshore operations have made a proper study for optimization selection very essential. The selected project must fulfill several requirements, namely: 1) Fit for the purpose, 2) Low risk and uncertainties, and 3) Economic. Hence, this study will describe the pilot project and continuous improvement process of lowering the gas well pressure using a wellhead compressor and a temporary separator to optimize the liquid loading. It also explains the implementation of critical gas rate in predicting the liquid loading event from the well’s production history. A new analysis method utilizing the adequacy chart was proposed to verify the suitability of the available pressure-lowering system unit available in the market with the well candidates. An adequacy chart was constructed from the well’s deliverability, critical gas rate, and lowering pressure unit or system capacity. These three charts will combine to generate an overlapping area, which signifies suitability for the recommended operation. The well’s production data history can be used to predict the liquid loaded-up event due to the continued decline of the generated gas. Also, a combination of the critical gas rate and decline analyses can predict potential liquid loading problems.
{"title":"The Implementation of Critical Gas Rate in Liquid Loading Well and Optimization Analysis using the Adequacy Chart","authors":"A. Ferdian, S. D. Rahmawati","doi":"10.25299/jeee.2021.6955","DOIUrl":"https://doi.org/10.25299/jeee.2021.6955","url":null,"abstract":"In the gas well, liquid loading occurs when the gas rate is insufficient to lift liquids into the surface such as water and/or condensate. This causes an accumulation of the liquid in the wellbore, supplies additional backpressure to the formation, and may completely kill the well. Meanwhile, the limited space and typically high cost of offshore operations have made a proper study for optimization selection very essential. The selected project must fulfill several requirements, namely: 1) Fit for the purpose, 2) Low risk and uncertainties, and 3) Economic. Hence, this study will describe the pilot project and continuous improvement process of lowering the gas well pressure using a wellhead compressor and a temporary separator to optimize the liquid loading. It also explains the implementation of critical gas rate in predicting the liquid loading event from the well’s production history. A new analysis method utilizing the adequacy chart was proposed to verify the suitability of the available pressure-lowering system unit available in the market with the well candidates. An adequacy chart was constructed from the well’s deliverability, critical gas rate, and lowering pressure unit or system capacity. These three charts will combine to generate an overlapping area, which signifies suitability for the recommended operation. The well’s production data history can be used to predict the liquid loaded-up event due to the continued decline of the generated gas. Also, a combination of the critical gas rate and decline analyses can predict potential liquid loading problems.","PeriodicalId":33635,"journal":{"name":"Journal of Earth Energy Engineering","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-11-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"46308049","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}
Hydrocarbon production in Indonesia is continuously decreasing on a yearly basis, which is in contrast with its increasing level of consumption. Low-quality and low-resistivity reservoir zones are deemed to possess a lot of hydrocarbon potentials, however, little priority has been placed on their development due to their small level of production. The "RI" field that was utilized in this study is a mature offshore field with a reservoir which has a low-quality and low-resistivity zone. This area has been in use for more than thirty years, therefore its rate of oil production has declined. This study aims to review the techno-economic aspects of well stimulation in the form of hydraulic fracturing. And also, to determine the development method that is suitable for low-quality fields. The hydraulic fracturing process was modelled using Fracpro software as input parameters for the reservoir production simulations. The reservoir behavior was simulated using the CMG software to observe the amount of hydrocarbon liable for production in various development scenarios. Three cases were performed on the "RI" field, which was stimulated for ten years of operation. The first case was the instance with the natural flow, while the second implemented hydraulic fracturing at the beginning of production, and the third was the implementation of hydraulic fracturing, which started in the middle of the production period. Then, the three cases are evaluated utilizing a Gross Split scheme, to calculate the economics of the project both from the government and contractor's aspects. The simulation study concluded that fracturing at the beginning of the LRLC zone development is the most profitable. The novelty of this study is the comparison of scenarios for the implementation of hydraulic fracturing methods in fields with low-resistivity and low-quality zone whose economic value is evaluated by the Gross Split scheme.
{"title":"Techno-Economic Analysis of Hydraulic Fracturing As A Solution for Developing Low-Resistivity and Low-Quality Zone on Offshore “RI” Field","authors":"S. Chandra, Ilma Mauldhya Herwandi","doi":"10.25299/jeee.2021.6588","DOIUrl":"https://doi.org/10.25299/jeee.2021.6588","url":null,"abstract":"Hydrocarbon production in Indonesia is continuously decreasing on a yearly basis, which is in contrast with its increasing level of consumption. Low-quality and low-resistivity reservoir zones are deemed to possess a lot of hydrocarbon potentials, however, little priority has been placed on their development due to their small level of production. The \"RI\" field that was utilized in this study is a mature offshore field with a reservoir which has a low-quality and low-resistivity zone. This area has been in use for more than thirty years, therefore its rate of oil production has declined. This study aims to review the techno-economic aspects of well stimulation in the form of hydraulic fracturing. And also, to determine the development method that is suitable for low-quality fields. The hydraulic fracturing process was modelled using Fracpro software as input parameters for the reservoir production simulations. The reservoir behavior was simulated using the CMG software to observe the amount of hydrocarbon liable for production in various development scenarios. Three cases were performed on the \"RI\" field, which was stimulated for ten years of operation. The first case was the instance with the natural flow, while the second implemented hydraulic fracturing at the beginning of production, and the third was the implementation of hydraulic fracturing, which started in the middle of the production period. Then, the three cases are evaluated utilizing a Gross Split scheme, to calculate the economics of the project both from the government and contractor's aspects. The simulation study concluded that fracturing at the beginning of the LRLC zone development is the most profitable. The novelty of this study is the comparison of scenarios for the implementation of hydraulic fracturing methods in fields with low-resistivity and low-quality zone whose economic value is evaluated by the Gross Split scheme.","PeriodicalId":33635,"journal":{"name":"Journal of Earth Energy Engineering","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-11-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"44535872","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 old oil and gas wells of approximately 70% are found to have no economic value in Indonesia, leading to being abandoned during the end of their lifecycle, as ruled by the government. This is part of decommissioning an entire field with an environmental preservation program, known as an Abandonment and Site Restoration (ASR). The program involves the evaluation of international permanent abandonment standards, as references for the designs, comparisons, and assessments of Indonesia’s policies. It also provides contrast gap analysis and suggestions in ensuring a proper permanent plug and abandonment approach, to avoid any future leaks or re-abandonment operations. Therefore, this study aims to determine and evaluate the gap analysis between Indonesia and International Well Abandonment Standards, as well as OGUK and NORSOK D-010. The results showed that abandonment activities had improvement opportunities philosophy, and practice, used for plugging/isolations, control lines, as well as reservoir and annular barriers. In addition, literature studies were performed to understand the abandonment philosophy for all reviewed standards, to provide proper suggestions or improvements.
{"title":"Indonesia Well Abandonment Standard Gap Analysis; A Review and Suggestion","authors":"G. R. Darmawan","doi":"10.25299/jeee.2021.6238","DOIUrl":"https://doi.org/10.25299/jeee.2021.6238","url":null,"abstract":"The old oil and gas wells of approximately 70% are found to have no economic value in Indonesia, leading to being abandoned during the end of their lifecycle, as ruled by the government. This is part of decommissioning an entire field with an environmental preservation program, known as an Abandonment and Site Restoration (ASR). The program involves the evaluation of international permanent abandonment standards, as references for the designs, comparisons, and assessments of Indonesia’s policies. It also provides contrast gap analysis and suggestions in ensuring a proper permanent plug and abandonment approach, to avoid any future leaks or re-abandonment operations. Therefore, this study aims to determine and evaluate the gap analysis between Indonesia and International Well Abandonment Standards, as well as OGUK and NORSOK D-010. The results showed that abandonment activities had improvement opportunities philosophy, and practice, used for plugging/isolations, control lines, as well as reservoir and annular barriers. In addition, literature studies were performed to understand the abandonment philosophy for all reviewed standards, to provide proper suggestions or improvements.","PeriodicalId":33635,"journal":{"name":"Journal of Earth Energy Engineering","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-11-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"49039272","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}
M. D. Anggoro, D. Siregar, R. Ninggar, S. Wicaksono, S. Lee
The solar PV systems are semiconductor devices that precisely convert sunlight into electricity, through the transfer of electrons. They provide several advantages, such as high modularity, zero noise, and adequate availability of solar resources in Indonesia. Therefore, this study aims to determine the potency, policy perspective, and Cost-Benefit Analysis (CBA) of the solar energy implementation for electricity generation. A statistical analysis was used for measuring potency, as well as reviewing opportunistic policies and barriers. A review of some CBA-based journals was also carried out, to determine that the development of solar power electricity had more benefit than fossil fuels and LCOE (Levelized Cost Of Electricity). The results of the 10-days average value calculation in 2019 were 388-563 W/m2, with the maximum values at 1137-1604 W/m2. Meanwhile the analysis of the maximum hourly averages for Western, Central, and Eastern Indonesia were 570-719, 634-758, and 559-627 W/m2 at 11.00-12.00 WIB, 11.00-13.00 WITA, and 12.00-13.00 WIT, respectively. The potency of solar radiation intensity in Indonesia was averagely 150-750 W/m2, as the highest values were found in East Nusa Tenggara, Maluku, and Merauke.
{"title":"Study of Indonesia’s Solar Energy Implementation Using Identification of Potency, Policies, and Cost-Benefit Analysis","authors":"M. D. Anggoro, D. Siregar, R. Ninggar, S. Wicaksono, S. Lee","doi":"10.25299/jeee.2021.6505","DOIUrl":"https://doi.org/10.25299/jeee.2021.6505","url":null,"abstract":"The solar PV systems are semiconductor devices that precisely convert sunlight into electricity, through the transfer of electrons. They provide several advantages, such as high modularity, zero noise, and adequate availability of solar resources in Indonesia. Therefore, this study aims to determine the potency, policy perspective, and Cost-Benefit Analysis (CBA) of the solar energy implementation for electricity generation. A statistical analysis was used for measuring potency, as well as reviewing opportunistic policies and barriers. A review of some CBA-based journals was also carried out, to determine that the development of solar power electricity had more benefit than fossil fuels and LCOE (Levelized Cost Of Electricity). The results of the 10-days average value calculation in 2019 were 388-563 W/m2, with the maximum values at 1137-1604 W/m2. Meanwhile the analysis of the maximum hourly averages for Western, Central, and Eastern Indonesia were 570-719, 634-758, and 559-627 W/m2 at 11.00-12.00 WIB, 11.00-13.00 WITA, and 12.00-13.00 WIT, respectively. The potency of solar radiation intensity in Indonesia was averagely 150-750 W/m2, as the highest values were found in East Nusa Tenggara, Maluku, and Merauke.","PeriodicalId":33635,"journal":{"name":"Journal of Earth Energy Engineering","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-11-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"42742605","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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