Debby Irawan, I. Wibowo, Bertha Martinauly, Linda Fransiska, L. Lilasari, D. Permanasari, Jhonny Jhonny
Tapping into an unconventional reservoir such as naturally fractured tight carbonate or basement has become more common in the industry. Open natural fractures, when present are the major contributor to production flow in such formation. Therefore, a comprehensive understanding of fracture properties including aperture, intensity, and permeability is required to identify the productive fractures and optimize production. In this paper, we discuss the first application of the latest Logging-While Drilling (LWD) high-resolution laterolog resistivity image in combination with LWD multi-pole sonic to provide comprehensive fracture characterization in Pre-Talang Akar Formation tight carbonate reservoir, in the offshore North West Java Basin, Indonesia. The methodology involved identification of borehole breakouts, natural or drilling-induced fractures, faults and vugs from the high-resolution LWD image data, which were then interpreted further to provide the fracture attributes and the secondary porosity distributions from each of the identified features. The Stoneley measurement from LWD multi-pole sonic log enabled the analysis of the fracture system producibility using the sonic fracture technique. The characterization of fractures and faults (open/closed) from the integration of these two independent methods were complemented by the triple combo measurements, caliper, and drilling loss data, as well as sonic compressional and shear data. This methodology has successfully managed to differentiate open fracture zones and closed fracture zones along with their computed fracture properties. The open fracture zones were characterized by a cluster of conductive fractures with large fracture aperture and fracture porosity value. These fractures were also associated with positive fracture indication from the sonic data, decrease in density logs, shallow - deep resistivity log separation and drilling loss occurrence. Whereas, closed fracture zones were characterized with minor fracture dip development. It also showed negative open fracture indication from sonic data, flat density log response and overlaying resistivity log response with no drilling loss occurrence. The case study in this paper shows excellent LWD data quality and fracture characterization result, on par with wireline conveyed data that were commonly used to quantify fracture attributes. The results provide invaluable information for volumetric calculation, well completion and production planning in this area.
{"title":"Comprehensive Fracture Characterization in Tight Carbonate Reservoir Using LWD High-Resolution Image and Multi-Pole Sonic Measurement; A Case Study from Offshore North West Java, Indonesia","authors":"Debby Irawan, I. Wibowo, Bertha Martinauly, Linda Fransiska, L. Lilasari, D. Permanasari, Jhonny Jhonny","doi":"10.2118/206244-ms","DOIUrl":"https://doi.org/10.2118/206244-ms","url":null,"abstract":"\u0000 Tapping into an unconventional reservoir such as naturally fractured tight carbonate or basement has become more common in the industry. Open natural fractures, when present are the major contributor to production flow in such formation. Therefore, a comprehensive understanding of fracture properties including aperture, intensity, and permeability is required to identify the productive fractures and optimize production.\u0000 In this paper, we discuss the first application of the latest Logging-While Drilling (LWD) high-resolution laterolog resistivity image in combination with LWD multi-pole sonic to provide comprehensive fracture characterization in Pre-Talang Akar Formation tight carbonate reservoir, in the offshore North West Java Basin, Indonesia. The methodology involved identification of borehole breakouts, natural or drilling-induced fractures, faults and vugs from the high-resolution LWD image data, which were then interpreted further to provide the fracture attributes and the secondary porosity distributions from each of the identified features. The Stoneley measurement from LWD multi-pole sonic log enabled the analysis of the fracture system producibility using the sonic fracture technique. The characterization of fractures and faults (open/closed) from the integration of these two independent methods were complemented by the triple combo measurements, caliper, and drilling loss data, as well as sonic compressional and shear data.\u0000 This methodology has successfully managed to differentiate open fracture zones and closed fracture zones along with their computed fracture properties. The open fracture zones were characterized by a cluster of conductive fractures with large fracture aperture and fracture porosity value. These fractures were also associated with positive fracture indication from the sonic data, decrease in density logs, shallow - deep resistivity log separation and drilling loss occurrence. Whereas, closed fracture zones were characterized with minor fracture dip development. It also showed negative open fracture indication from sonic data, flat density log response and overlaying resistivity log response with no drilling loss occurrence.\u0000 The case study in this paper shows excellent LWD data quality and fracture characterization result, on par with wireline conveyed data that were commonly used to quantify fracture attributes. The results provide invaluable information for volumetric calculation, well completion and production planning in this area.","PeriodicalId":10965,"journal":{"name":"Day 3 Thu, September 23, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84679119","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
This paper presents a fit-for-purpose gas well performance model that utilizes a minimum set of inflow and outflow performance parameters, and demonstrates the use of this model to describe real-time well performance, to compare well performance over time and between wells, and to generate production forecasts in support of well interventions. The inflow and outflow parameters are directly related to well-known reservoir and well properties, and can be calibrated against common well surveillance and production data. By adopting this approach, engineers develop a better appreciation of the magnitude and uncertainty of gas well and reservoir performance parameters.
{"title":"Data Driven Gas Well Performance Model Hands Back Control to Engineers","authors":"C. Veeken","doi":"10.2118/206192-ms","DOIUrl":"https://doi.org/10.2118/206192-ms","url":null,"abstract":"\u0000 This paper presents a fit-for-purpose gas well performance model that utilizes a minimum set of inflow and outflow performance parameters, and demonstrates the use of this model to describe real-time well performance, to compare well performance over time and between wells, and to generate production forecasts in support of well interventions. The inflow and outflow parameters are directly related to well-known reservoir and well properties, and can be calibrated against common well surveillance and production data. By adopting this approach, engineers develop a better appreciation of the magnitude and uncertainty of gas well and reservoir performance parameters.","PeriodicalId":10965,"journal":{"name":"Day 3 Thu, September 23, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83446181","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. A. Giraldo, R. Zabala, J. I. Bahamón, Camilo Mazo, J. Guzman, Camilo A. Franco, F. Cortés
This work aims to develop a fracturing nanofluid with a dual purpose: i) to increase heavy crude oil mobility and ii) to reduce formation damage caused by the remaining fluid. Three commercial nanoparticles were evaluated: two fumed silica of different sizes and one type of alumina. They were acidified and basified, obtaining nine nanoparticles (NPs) by the surface modification, characterized by TEM, DLS, Z Potential and Total Acidity. The effect of adding nanoparticles at different concentrations onto the linear gel and heavy crude oil was determined by their rheological behavior. Also, there was assessed the alteration of the rock wettability by contact angle for all NPs and concentrations. Based on these results, the nanoparticle with better performance was the neutral fumed silica of 7 nm at 1000 mg/L. These were used to make a fracturing nanofluid from a commercial fracturing fluid (FF). Both of them were evaluated through their rheological behavior overtime at high pressure following the API RP39 test and quantitative measurements of the rock sample wettability changes. Displacement tests also were performed on proppant and rock samples at reservoir conditions: pressure and temperature. Finally, there was evaluated the rheological behavior of the crude oil recovered in the displacement test. It was possible to conclude that the inclusion of nanoparticles allowed obtaining a reduction of 10 and 20% in the two breakers used in the commercial fracture fluid formulation. An alteration of the rock wettability was achieved, where the rock sample became up to 50% more wettable to water. Moreover, there was a diminution of 53% in the damage caused by the remaining fracturing fluid to the oil effective permeability in the proppant medium. In the rock sample, a decrease of 31% of this kind of damage was observed. Increases of 28 and 18 % in the crude oil recovery were noticed in the proppant and the rock sample, respectively. Finally, there was a reduction of 40% in the crude oil viscosity, showing the effectiveness of adding nanoparticles to fracturing fluids for increasing oil mobility and reducing the formation damage.
{"title":"Development of a Fracturing Nanofluid with Dual Purpose: Increasing Heavy Oil Mobility and Reducing the Reservoir Damage Associated at the Remaining Fracture Fluid","authors":"M. A. Giraldo, R. Zabala, J. I. Bahamón, Camilo Mazo, J. Guzman, Camilo A. Franco, F. Cortés","doi":"10.2118/205976-ms","DOIUrl":"https://doi.org/10.2118/205976-ms","url":null,"abstract":"\u0000 This work aims to develop a fracturing nanofluid with a dual purpose: i) to increase heavy crude oil mobility and ii) to reduce formation damage caused by the remaining fluid. Three commercial nanoparticles were evaluated: two fumed silica of different sizes and one type of alumina. They were acidified and basified, obtaining nine nanoparticles (NPs) by the surface modification, characterized by TEM, DLS, Z Potential and Total Acidity. The effect of adding nanoparticles at different concentrations onto the linear gel and heavy crude oil was determined by their rheological behavior. Also, there was assessed the alteration of the rock wettability by contact angle for all NPs and concentrations. Based on these results, the nanoparticle with better performance was the neutral fumed silica of 7 nm at 1000 mg/L. These were used to make a fracturing nanofluid from a commercial fracturing fluid (FF). Both of them were evaluated through their rheological behavior overtime at high pressure following the API RP39 test and quantitative measurements of the rock sample wettability changes. Displacement tests also were performed on proppant and rock samples at reservoir conditions: pressure and temperature. Finally, there was evaluated the rheological behavior of the crude oil recovered in the displacement test. It was possible to conclude that the inclusion of nanoparticles allowed obtaining a reduction of 10 and 20% in the two breakers used in the commercial fracture fluid formulation. An alteration of the rock wettability was achieved, where the rock sample became up to 50% more wettable to water. Moreover, there was a diminution of 53% in the damage caused by the remaining fracturing fluid to the oil effective permeability in the proppant medium. In the rock sample, a decrease of 31% of this kind of damage was observed. Increases of 28 and 18 % in the crude oil recovery were noticed in the proppant and the rock sample, respectively. Finally, there was a reduction of 40% in the crude oil viscosity, showing the effectiveness of adding nanoparticles to fracturing fluids for increasing oil mobility and reducing the formation damage.","PeriodicalId":10965,"journal":{"name":"Day 3 Thu, September 23, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85936310","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}
Ahmed. N. Alduaij, Z. Al-Bensaad, Mauricio Espinosa, D. Ahmed, Madhurjya Dehingia
Successful coiled tubing (CT) descaling interventions require control of several key aspects, including fluid leakoff into the formation, proper surface solids handling, and controlled hydrogen sulfide (H2S) release at the surface. Successful treatment control is achieved by monitoring the surface and downhole parameters. The recently introduced pressure and fluid management system, crosslinked foam-based fluid, and a fluid mixing system for CT descaling treatments pose challenges that require enhancements to these elements for successful treatment. The pressure and fluid management system was enhanced to include a new high-rate mud/gas separator to 1) increase gas/fluid separation capacity and avoid foam flowing to flare, 2) rig up the flare line with inclination to allow all water to be drained and prevent formation gas flowing to flare lines, and 3) increase retention time for better foam breaking and material settling. A liquid flowmeter was also added to improve influx and leakoff control by monitoring the volume of liquid injected and matching the volume of liquid returned on surface in addition to the level gauges on the return tanks of the pressure and fluid management system. The foamed-based fluid breaking system and H2S presence in returns were mitigated by removing crosslinker and introducing an H2S scavenger on returns whereas foam breaking was enhanced by additional breaker injection points on returns. Fluid mixing capabilities were enhanced by the introduction of an on-the-fly continuous mixing system that sped up and simplified the mixing process. The mud/gas separator efficiently separated the gas from liquid, leading the gas to be burnt at flare and the liquid to be processed in the pressure and fluid management system. It further helped in preventing the liquid flowing to flare, which lessened the risk of flare shutdown and H2S ventilation. The on-the-fly continuous mixing system provided a faster and more-efficient mixing process as an alternate to batch mixing. These system-controlled metering, mixing, and monitoring capabilities significantly reduced the crew and equipment footprint, leading to minimizing the health, safety, and environment (HSE) concerns and cost savings. The fluid flowmeter allowed efficient choke and bottom-hole pressure control. Fluid flowmeter readings helped in choke and bottom-hole pressure reading adjustments based on amount of fluids pumped and matching the same amount of fluids returned at the surface. It prevented the fluid leakoff into the formation or influx of gas into the wellbore. Additionally, this new process created better control of downhole differential pressure during the scale cleanup and transportation. This project integrated different technologies and techniques that can be utilized for descaling treatment enhancements. The recent enhancements to the CT descaling operation resulted in greater efficiency, cost savings, reduced formation damage, and safe operations.
{"title":"Recent Enhancements for Coiled Tubing Descaling Treatments in Middle East","authors":"Ahmed. N. Alduaij, Z. Al-Bensaad, Mauricio Espinosa, D. Ahmed, Madhurjya Dehingia","doi":"10.2118/205891-ms","DOIUrl":"https://doi.org/10.2118/205891-ms","url":null,"abstract":"\u0000 Successful coiled tubing (CT) descaling interventions require control of several key aspects, including fluid leakoff into the formation, proper surface solids handling, and controlled hydrogen sulfide (H2S) release at the surface. Successful treatment control is achieved by monitoring the surface and downhole parameters. The recently introduced pressure and fluid management system, crosslinked foam-based fluid, and a fluid mixing system for CT descaling treatments pose challenges that require enhancements to these elements for successful treatment.\u0000 The pressure and fluid management system was enhanced to include a new high-rate mud/gas separator to 1) increase gas/fluid separation capacity and avoid foam flowing to flare, 2) rig up the flare line with inclination to allow all water to be drained and prevent formation gas flowing to flare lines, and 3) increase retention time for better foam breaking and material settling. A liquid flowmeter was also added to improve influx and leakoff control by monitoring the volume of liquid injected and matching the volume of liquid returned on surface in addition to the level gauges on the return tanks of the pressure and fluid management system. The foamed-based fluid breaking system and H2S presence in returns were mitigated by removing crosslinker and introducing an H2S scavenger on returns whereas foam breaking was enhanced by additional breaker injection points on returns. Fluid mixing capabilities were enhanced by the introduction of an on-the-fly continuous mixing system that sped up and simplified the mixing process.\u0000 The mud/gas separator efficiently separated the gas from liquid, leading the gas to be burnt at flare and the liquid to be processed in the pressure and fluid management system. It further helped in preventing the liquid flowing to flare, which lessened the risk of flare shutdown and H2S ventilation.\u0000 The on-the-fly continuous mixing system provided a faster and more-efficient mixing process as an alternate to batch mixing. These system-controlled metering, mixing, and monitoring capabilities significantly reduced the crew and equipment footprint, leading to minimizing the health, safety, and environment (HSE) concerns and cost savings.\u0000 The fluid flowmeter allowed efficient choke and bottom-hole pressure control. Fluid flowmeter readings helped in choke and bottom-hole pressure reading adjustments based on amount of fluids pumped and matching the same amount of fluids returned at the surface. It prevented the fluid leakoff into the formation or influx of gas into the wellbore.\u0000 Additionally, this new process created better control of downhole differential pressure during the scale cleanup and transportation. This project integrated different technologies and techniques that can be utilized for descaling treatment enhancements. The recent enhancements to the CT descaling operation resulted in greater efficiency, cost savings, reduced formation damage, and safe operations.","PeriodicalId":10965,"journal":{"name":"Day 3 Thu, September 23, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83189030","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}
Emerging technologies often bring new opportunities to enhance productivity and safety in the oil and gas industry. New technologies and opportunities often come with the challenges of workforce development to provide entry-level and current professionals with the necessary training and skillset. This paper presents a vertical education enhancement (VEE) model approach to providing emerging skillset needs in the oil and gas industry with emphases on curriculum continuous improvement and lifelong learning. The top new and emerging technologies that are critical to the future of the oil and gas industry in enhancing productivity and safety include Internet of Things (IoT), artificial intelligence, big data analytics, cloud computing, and 3D modeling/visualization. As part of the solution to train the oil and gas industry workforce to meet the challenges of adopting these technologies, the VEE model features a vertical education structure that encompasses outreach to K-12 education, recruitment, tertiary education, professional training, and lifelong learning. It has an interwoven fundamental structure consisting of curriculum and mentorship, partnerships with stakeholders (industry, government, and community), and research and funding. The VEE model has periodic assessment continuous improvement processes for identifying emerging technologies and new skillset needed to improve the workforce. These processes are like those practiced by accreditation bodies such Accreditation Board for Engineering and Technology (ABET), United Kingdom Accreditation Services (UKAS), and Offshore Petroleum Industry Training Organization (OPITO). Diversity to increase the participation of underrepresented minority groups and women in engineering would further increase the workforce. The novelty that the VEE model approach brings is the effectiveness in providing skillset training in new and emerging technologies for the oil and gas industry at all levels of workforce development. These include content infusion in existing courses, special-topic and specialized courses at senior and graduate levels, and professional development education and training through lifelong learning platforms.
{"title":"Vertical Education Enhancement Approach to Meeting Emerging Skillset Needs in Oil and Gas Industry","authors":"S. Egarievwe, Jamie A. Johnson, E. Agbalagba","doi":"10.2118/206087-ms","DOIUrl":"https://doi.org/10.2118/206087-ms","url":null,"abstract":"\u0000 Emerging technologies often bring new opportunities to enhance productivity and safety in the oil and gas industry. New technologies and opportunities often come with the challenges of workforce development to provide entry-level and current professionals with the necessary training and skillset. This paper presents a vertical education enhancement (VEE) model approach to providing emerging skillset needs in the oil and gas industry with emphases on curriculum continuous improvement and lifelong learning. The top new and emerging technologies that are critical to the future of the oil and gas industry in enhancing productivity and safety include Internet of Things (IoT), artificial intelligence, big data analytics, cloud computing, and 3D modeling/visualization. As part of the solution to train the oil and gas industry workforce to meet the challenges of adopting these technologies, the VEE model features a vertical education structure that encompasses outreach to K-12 education, recruitment, tertiary education, professional training, and lifelong learning. It has an interwoven fundamental structure consisting of curriculum and mentorship, partnerships with stakeholders (industry, government, and community), and research and funding. The VEE model has periodic assessment continuous improvement processes for identifying emerging technologies and new skillset needed to improve the workforce. These processes are like those practiced by accreditation bodies such Accreditation Board for Engineering and Technology (ABET), United Kingdom Accreditation Services (UKAS), and Offshore Petroleum Industry Training Organization (OPITO). Diversity to increase the participation of underrepresented minority groups and women in engineering would further increase the workforce. The novelty that the VEE model approach brings is the effectiveness in providing skillset training in new and emerging technologies for the oil and gas industry at all levels of workforce development. These include content infusion in existing courses, special-topic and specialized courses at senior and graduate levels, and professional development education and training through lifelong learning platforms.","PeriodicalId":10965,"journal":{"name":"Day 3 Thu, September 23, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89762556","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}
Cao Wei, Shiqing Cheng, Bin Jiang, Ruilian Gao, Yang Wang, Jiayi Song, Haiyang Yu
An important way to develop geothermal energy is by producing low-medium temperature fluids from naturally fractured geothermal reservoirs. Pressure analysis is the most used to characterize such reservoirs for improving development efficiency. However, pressure inversion easily leads to non-uniqueness and cannot estimate thermal properties. Additionally, no reliable methods are proposed to evaluate the development potential of geothermal reservoirs. To narrow the gap, this study aims at studying the temperature behaviors and exploring suitable analysis method for characterizing geothermal reservoir and evaluating development potential. The numerical and analytical models are simultaneously established to analyze the temperature behaviors. Our models account for the J-T effect (μJT), adiabatic heat expansion/compression effect (η), reservoir damage, viscous dissipation, heat conduction and convection effects. The solution's development is dependent on the fact that the effects of reservoir temperature changes on transient pressure can be ignored so that the pressure and energy equations can be decoupled. We firstly compute reservoir pressure field based on Kazemi model, then use this obtained pressure field to solve the energy-balance equations. The numerical solution is verified and is found to be in good agreement with the proposed analytical solutions. This work shows that the most used constant μJT and η assumption will produce inaccurate temperature results when reservoir temperature changes significantly. Moreover, we find that temperature behaviors can exhibit three heat radial flow regimes (HRFR) and a heat inter-porosity regime with V-shape characteristic. Fracture thermal storativity ratio and matrix heat inter-porosity coefficient defined in this study can be estimated from this characteristic, which are further used to evaluate geothermal development potential. Our work also shows that temperature data can give information that would not be provided by conventional pressure analysis. The temperature derivative curve will show ‘hump’ characteristic if reservoir is damaged. The temperature data can characterize the skin-zone radius and permeability. More than that, the properties such as J-T coefficient, effective adiabatic heat expansion coefficient and porosity can be estimated. Eventually, an integrated workflow of using both temperature and pressure data analysis is presented to characterize naturally fractured geothermal reservoir for the first time. Simulated test examples were interpreted to demonstrate its applicability.
{"title":"Numerical Study on the Temperature Behavior in Naturally Fractured Geothermal Reservoirs and Analysis Methodology for Geothermal Reservoir Characterization and Development","authors":"Cao Wei, Shiqing Cheng, Bin Jiang, Ruilian Gao, Yang Wang, Jiayi Song, Haiyang Yu","doi":"10.2118/205862-ms","DOIUrl":"https://doi.org/10.2118/205862-ms","url":null,"abstract":"\u0000 An important way to develop geothermal energy is by producing low-medium temperature fluids from naturally fractured geothermal reservoirs. Pressure analysis is the most used to characterize such reservoirs for improving development efficiency. However, pressure inversion easily leads to non-uniqueness and cannot estimate thermal properties. Additionally, no reliable methods are proposed to evaluate the development potential of geothermal reservoirs. To narrow the gap, this study aims at studying the temperature behaviors and exploring suitable analysis method for characterizing geothermal reservoir and evaluating development potential.\u0000 The numerical and analytical models are simultaneously established to analyze the temperature behaviors. Our models account for the J-T effect (μJT), adiabatic heat expansion/compression effect (η), reservoir damage, viscous dissipation, heat conduction and convection effects. The solution's development is dependent on the fact that the effects of reservoir temperature changes on transient pressure can be ignored so that the pressure and energy equations can be decoupled. We firstly compute reservoir pressure field based on Kazemi model, then use this obtained pressure field to solve the energy-balance equations. The numerical solution is verified and is found to be in good agreement with the proposed analytical solutions.\u0000 This work shows that the most used constant μJT and η assumption will produce inaccurate temperature results when reservoir temperature changes significantly. Moreover, we find that temperature behaviors can exhibit three heat radial flow regimes (HRFR) and a heat inter-porosity regime with V-shape characteristic. Fracture thermal storativity ratio and matrix heat inter-porosity coefficient defined in this study can be estimated from this characteristic, which are further used to evaluate geothermal development potential. Our work also shows that temperature data can give information that would not be provided by conventional pressure analysis. The temperature derivative curve will show ‘hump’ characteristic if reservoir is damaged. The temperature data can characterize the skin-zone radius and permeability. More than that, the properties such as J-T coefficient, effective adiabatic heat expansion coefficient and porosity can be estimated. Eventually, an integrated workflow of using both temperature and pressure data analysis is presented to characterize naturally fractured geothermal reservoir for the first time. Simulated test examples were interpreted to demonstrate its applicability.","PeriodicalId":10965,"journal":{"name":"Day 3 Thu, September 23, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73899009","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}
While the demand for hydrocarbon resources has been continuously increasing in the past 150 years, the industry is, however, criticized for carbon dioxide (CO2) emissions and concomitant global warming concerns. The oil and gas industry also face growing pressures in the ongoing energy transition. Generating and producing hydrogen (H2) directly from petroleum reservoirs has the potential to mitigate environmental impacts while revolutionizing the traditional petroleum industry and enabling it to become a clean hydrogen industry. This paper proposes a novel approach to generate high-purity, CO2-free hydrogen from the abundant oil and gas resources in petroleum reservoirs using microwave heating. In this work, laboratory experiments were conducted to validate this scientific proof-of-concept and examine the roles of crushed rocks, catalysts, and water/oil ratio in hydrogen generation from crude oils in a reactor. A maximum of 63% ultimate hydrogen content is obtained in the generated gas mixtures, while the original CO2content in all experiments is negligible (<1%). Catalysts can promote hydrogen generation by accelerating rate and locally enhancing microwave (MW) absorption to create ‘super-hot spots'. Water also participates in reactions, and additional hydrogen is generated through water-gas shift reactions. The water-oil ratio in porous rocks affects the ultimate hydrogen yield. Overall, this research demonstrates the great potential of using MW heating to generate high-purity, CO2-free hydrogen from in situ petroleum reservoirs. Further research and wide application of this technology would potentially transform petroleum reservoirs to hydrogen generators, thus mitigating the environmental impacts of traditional petroleum industry while meeting the increasing demand for clean hydrogen energy. This technology would also benefit the safe transition towards a decarbonized society.
{"title":"High-Purity, CO2-Free Hydrogen Generation from Crude Oils in Crushed Rocks Using Microwave Heating","authors":"Q. Yuan, Xiangyu Jie, Bo Ren","doi":"10.2118/206341-ms","DOIUrl":"https://doi.org/10.2118/206341-ms","url":null,"abstract":"\u0000 While the demand for hydrocarbon resources has been continuously increasing in the past 150 years, the industry is, however, criticized for carbon dioxide (CO2) emissions and concomitant global warming concerns. The oil and gas industry also face growing pressures in the ongoing energy transition. Generating and producing hydrogen (H2) directly from petroleum reservoirs has the potential to mitigate environmental impacts while revolutionizing the traditional petroleum industry and enabling it to become a clean hydrogen industry.\u0000 This paper proposes a novel approach to generate high-purity, CO2-free hydrogen from the abundant oil and gas resources in petroleum reservoirs using microwave heating. In this work, laboratory experiments were conducted to validate this scientific proof-of-concept and examine the roles of crushed rocks, catalysts, and water/oil ratio in hydrogen generation from crude oils in a reactor. A maximum of 63% ultimate hydrogen content is obtained in the generated gas mixtures, while the original CO2content in all experiments is negligible (<1%). Catalysts can promote hydrogen generation by accelerating rate and locally enhancing microwave (MW) absorption to create ‘super-hot spots'. Water also participates in reactions, and additional hydrogen is generated through water-gas shift reactions. The water-oil ratio in porous rocks affects the ultimate hydrogen yield. Overall, this research demonstrates the great potential of using MW heating to generate high-purity, CO2-free hydrogen from in situ petroleum reservoirs. Further research and wide application of this technology would potentially transform petroleum reservoirs to hydrogen generators, thus mitigating the environmental impacts of traditional petroleum industry while meeting the increasing demand for clean hydrogen energy. This technology would also benefit the safe transition towards a decarbonized society.","PeriodicalId":10965,"journal":{"name":"Day 3 Thu, September 23, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74903319","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}
I. Baghishov, Gayan A. Abeykoon, Mingyuan Wang, Francisco J. Argüelles Vivas, R. Okuno
Previous studies indicated the efficacy of the simplest amino acid, glycine, as an aqueous additive for enhanced water imbibition in carbonate reservoirs. The objective of this research was to investigate the importance of the amino group of glycine in its enhanced water imbibition. To this end, glycine was compared with two carboxylates (acetate and formate) with/without adding hydrogen chloride (HCl) for adjusting the solution pH. Note that the amino group is the only difference between glycine and acetate. Contact-angle experiments on calcite were carried out at 347 K and atmospheric pressure with 68000-ppm reservoir brine (RB), and 4 different concentrations of glycine, acetate, and formate solutions in RB. To test the hypothesis that calcite dissolution is one of the main mechanisms in wettability alteration by glycine, we performed another set of contact angle experiments by adding HCl to brine, acetate, and formate solutions. HCl was added to match the pH of the glycine solution at the same concentration. We also performed imbibition tests with Texas Cream Limestone cores at 347 K with brine, glycine, acetate, and formate solutions (with and without HCl) in RB at 5.0 wt%. Contact-angle results indicated that glycine changed calcite's wettability from oil-wet to water-wet (45°). However, acetate solution was not able to change the wettability to water-wet; and formate moderately decreased the contact angle to 80°. The pH level increased from 6.1 to 7.6 after the contact angle experiment in glycine solution, indicating the consumption of hydrogen ions due to calcite dissolution. The levels of pH in formate and acetate solutions, however, decreased from 8.4 to 7.8. The acidity of glycine above its isoelectric point arises from the deprotonation of the carboxyl group. Imbibition tests with carbonate cores supported the observations from the contact-angle experiments. The oil recovery was 31% for glycine solution, 20% for RB, 21% for formate solution, and 19% for acetate solution. This re-confirmed the effectiveness of glycine as an additive to improve the oil recovery from carbonates. An additional set of imbibition tests revealed that acetate at the pH reduced to the same level as glycine was still not able to recover as much oil as glycine. This showed that glycine recovered oil not only because of the calcite dissolution and the carboxyl group, but also because of the amino group. It is hypothesized that the amino group with its electron donor ability creates a chelation effect that makes glycine entropically more favorable to get attached to the calcite surface than acetate. Another important result is that the formate solution at an adjusted pH resulted in a greater oil recovery than RB or RB at the same pH. This indicates that there is an optimal pH for the carboxyl group to be effective in wettability alteration as also indicated by the pH change during the contact-angle experiment.
{"title":"Glycine for Enhanced Water Imbibition in Carbonate Reservoirs – What is the Role of Amino Group?","authors":"I. Baghishov, Gayan A. Abeykoon, Mingyuan Wang, Francisco J. Argüelles Vivas, R. Okuno","doi":"10.2118/206294-ms","DOIUrl":"https://doi.org/10.2118/206294-ms","url":null,"abstract":"\u0000 Previous studies indicated the efficacy of the simplest amino acid, glycine, as an aqueous additive for enhanced water imbibition in carbonate reservoirs. The objective of this research was to investigate the importance of the amino group of glycine in its enhanced water imbibition. To this end, glycine was compared with two carboxylates (acetate and formate) with/without adding hydrogen chloride (HCl) for adjusting the solution pH. Note that the amino group is the only difference between glycine and acetate.\u0000 Contact-angle experiments on calcite were carried out at 347 K and atmospheric pressure with 68000-ppm reservoir brine (RB), and 4 different concentrations of glycine, acetate, and formate solutions in RB. To test the hypothesis that calcite dissolution is one of the main mechanisms in wettability alteration by glycine, we performed another set of contact angle experiments by adding HCl to brine, acetate, and formate solutions. HCl was added to match the pH of the glycine solution at the same concentration. We also performed imbibition tests with Texas Cream Limestone cores at 347 K with brine, glycine, acetate, and formate solutions (with and without HCl) in RB at 5.0 wt%.\u0000 Contact-angle results indicated that glycine changed calcite's wettability from oil-wet to water-wet (45°). However, acetate solution was not able to change the wettability to water-wet; and formate moderately decreased the contact angle to 80°. The pH level increased from 6.1 to 7.6 after the contact angle experiment in glycine solution, indicating the consumption of hydrogen ions due to calcite dissolution. The levels of pH in formate and acetate solutions, however, decreased from 8.4 to 7.8. The acidity of glycine above its isoelectric point arises from the deprotonation of the carboxyl group.\u0000 Imbibition tests with carbonate cores supported the observations from the contact-angle experiments. The oil recovery was 31% for glycine solution, 20% for RB, 21% for formate solution, and 19% for acetate solution. This re-confirmed the effectiveness of glycine as an additive to improve the oil recovery from carbonates. An additional set of imbibition tests revealed that acetate at the pH reduced to the same level as glycine was still not able to recover as much oil as glycine. This showed that glycine recovered oil not only because of the calcite dissolution and the carboxyl group, but also because of the amino group. It is hypothesized that the amino group with its electron donor ability creates a chelation effect that makes glycine entropically more favorable to get attached to the calcite surface than acetate.\u0000 Another important result is that the formate solution at an adjusted pH resulted in a greater oil recovery than RB or RB at the same pH. This indicates that there is an optimal pH for the carboxyl group to be effective in wettability alteration as also indicated by the pH change during the contact-angle experiment.","PeriodicalId":10965,"journal":{"name":"Day 3 Thu, September 23, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73953415","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}
Ozgur Karacali, Khaled Hassan Elhassi, B. Theuveny, Abdunnaser Ali Y Elmashergai, Anis Lotfi El Gihani, Abdelaziz Zorgane
The fundamental objective of well perforating is to launch an optimum wellbore to reservoir communication. Unfortunately, not all perforating jobs deliver ideal communication quality. In this paper the rudiments of apposite perforating operations, from data integration and job design to safe implementation, are summarized to produce practical guidelines for high productivity perforating jobs. Reviving oil production in mature fields is a major challenge around the globe. In Libya, there are several mature oil and gas fields that requires production enhancement. In some of these fields the challenge was to come up with a methodology that improves the oil production with minimal well intervention while testing the wells in a much quicker way than the conventional wireline conveyed perforating, well kill, swab, and test techniques. Producing zones in Libyan oil fields have lost productivity over the years due to various activities associated with workover operations. Damage was mainly caused by existence of high salinity formation water and unfiltered brine usage to kill or control the wells. Research has proven that wellbore dynamics have a substantial impact on the success of perforating activities during this very high-paced and short-lived event. We have used a technique that combines the static and the dynamic underbalanced perforating techniques to ultimately improve the hydrocarbon production in such mature fields. Advanced downhole gun and charge system designs and downhole tools are combined to enhance oil production. Debris, scale, and crushed rock removal from the perforation tunnels by applying static underbalanced perforating techniques works very successfully in many cases. Numerous field examples and research have also shown that dynamic underbalance can greatly enhance the tunnel clean up and well productivity. In this paper we are showing that combining static and dynamic underbalanced perforating ensures the optimum perforation tunnel structure. We have applied this technique on numerous wells for the purposes of perforating and re-perforating. Several wells were reperforated to improve the well to reservoir communication quality of existing plugged and damaged perforating zones. In most of the cases new perforating intervals were also added based on production logging and reservoir saturation log results. We have gained extraordinary oil production for several wells. This methodology with improved design increased oil production more than 400% in some wells. Results of this study are presented in an easy to follow way to ensure learnings are passed on to the industry for achieving improved results elsewhere. The techniques outlined in this paper will permit enhanced perforation designs via utilizing available software packages in challenging environments where conventional approaches can be inadequate. The methodology described in this paper is unique in terms of combining the existing techniques in an accessible way.
{"title":"Unique Underbalanced Perforating Technique Reveals Unexpected Remaining Oil in Shut-In Wells in Libya","authors":"Ozgur Karacali, Khaled Hassan Elhassi, B. Theuveny, Abdunnaser Ali Y Elmashergai, Anis Lotfi El Gihani, Abdelaziz Zorgane","doi":"10.2118/206342-ms","DOIUrl":"https://doi.org/10.2118/206342-ms","url":null,"abstract":"\u0000 The fundamental objective of well perforating is to launch an optimum wellbore to reservoir communication. Unfortunately, not all perforating jobs deliver ideal communication quality. In this paper the rudiments of apposite perforating operations, from data integration and job design to safe implementation, are summarized to produce practical guidelines for high productivity perforating jobs.\u0000 Reviving oil production in mature fields is a major challenge around the globe. In Libya, there are several mature oil and gas fields that requires production enhancement. In some of these fields the challenge was to come up with a methodology that improves the oil production with minimal well intervention while testing the wells in a much quicker way than the conventional wireline conveyed perforating, well kill, swab, and test techniques. Producing zones in Libyan oil fields have lost productivity over the years due to various activities associated with workover operations. Damage was mainly caused by existence of high salinity formation water and unfiltered brine usage to kill or control the wells. Research has proven that wellbore dynamics have a substantial impact on the success of perforating activities during this very high-paced and short-lived event. We have used a technique that combines the static and the dynamic underbalanced perforating techniques to ultimately improve the hydrocarbon production in such mature fields. Advanced downhole gun and charge system designs and downhole tools are combined to enhance oil production.\u0000 Debris, scale, and crushed rock removal from the perforation tunnels by applying static underbalanced perforating techniques works very successfully in many cases. Numerous field examples and research have also shown that dynamic underbalance can greatly enhance the tunnel clean up and well productivity. In this paper we are showing that combining static and dynamic underbalanced perforating ensures the optimum perforation tunnel structure. We have applied this technique on numerous wells for the purposes of perforating and re-perforating. Several wells were reperforated to improve the well to reservoir communication quality of existing plugged and damaged perforating zones. In most of the cases new perforating intervals were also added based on production logging and reservoir saturation log results. We have gained extraordinary oil production for several wells. This methodology with improved design increased oil production more than 400% in some wells.\u0000 Results of this study are presented in an easy to follow way to ensure learnings are passed on to the industry for achieving improved results elsewhere. The techniques outlined in this paper will permit enhanced perforation designs via utilizing available software packages in challenging environments where conventional approaches can be inadequate. The methodology described in this paper is unique in terms of combining the existing techniques in an accessible way.","PeriodicalId":10965,"journal":{"name":"Day 3 Thu, September 23, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76724028","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}
Christian Petersen, O. Strand, E. Johansen, Dag Almar Hansen, D. Fredheim, P. Ohlckers
Pressure control have been going through steps of evolution. In the highlight of safety, reliability and control, the systems have been sturdy withstanding massive pressure and environmental impact to last the time of estimated life of well. Design have been emphasizing on sturdiness rather than intelligence and autonomy. Time moves on, sophistication levels rise in all parts of our industry. Sustainability and lower environmental impact of solutions grow from the young into business planning and democratic policies. Control lines of hydraulic systems posed risks to the environment as well as being costly in structure and maintenance. Condition monitoring helped ensure better maintenance planning and lowered the risk of breakdown, but still left a lot to be desired reaching for self-contained, self learning systems with low installation and maintenance costs, yet the safest approach. The next steps were taken towards electrification and digitization of pressure control systems, making short and undetermined strides over almost two decades. Still, the standards are not following the pace of technological progress. And when someone dares to pilot or demonstrate modern technology applied, the installations and operational procedures of the systems still need expensive distributed lines of power, of signals and control systems to ensure a swift and safe operation. The fly-by-wire principle applied in oil & gas is the operate-by-costly-technology-and-environmental-impact-lines. With the introduction of new and breaking technology in energy harvesting and storage, the playing field opens up towards fully automated systems with no need for expensive power lines or hydraulic control lines. The safety will be taken care of also off-grid, fully digitized. Should cabling of instrument signals be damaged, the system of tomorrow will still be up to par with the Safety Integrity Levels needed. New super-capacitors with an extra dense storage capacity being developed in partnership between the industry and the University of southeast Norway combined with an extremely low energy consuming actuation system with the fastest failsafe mechanism ever will ensure safety in all modes of operation, even with all lines down or consumed by flames. The paper aims to show how the technology works and underline why it will take a place in the future of well control and production.
{"title":"PACT - One Step Closer to Well Control Autonomy","authors":"Christian Petersen, O. Strand, E. Johansen, Dag Almar Hansen, D. Fredheim, P. Ohlckers","doi":"10.2118/206274-ms","DOIUrl":"https://doi.org/10.2118/206274-ms","url":null,"abstract":"\u0000 Pressure control have been going through steps of evolution. In the highlight of safety, reliability and control, the systems have been sturdy withstanding massive pressure and environmental impact to last the time of estimated life of well. Design have been emphasizing on sturdiness rather than intelligence and autonomy. Time moves on, sophistication levels rise in all parts of our industry. Sustainability and lower environmental impact of solutions grow from the young into business planning and democratic policies. Control lines of hydraulic systems posed risks to the environment as well as being costly in structure and maintenance. Condition monitoring helped ensure better maintenance planning and lowered the risk of breakdown, but still left a lot to be desired reaching for self-contained, self learning systems with low installation and maintenance costs, yet the safest approach.\u0000 The next steps were taken towards electrification and digitization of pressure control systems, making short and undetermined strides over almost two decades. Still, the standards are not following the pace of technological progress. And when someone dares to pilot or demonstrate modern technology applied, the installations and operational procedures of the systems still need expensive distributed lines of power, of signals and control systems to ensure a swift and safe operation. The fly-by-wire principle applied in oil & gas is the operate-by-costly-technology-and-environmental-impact-lines.\u0000 With the introduction of new and breaking technology in energy harvesting and storage, the playing field opens up towards fully automated systems with no need for expensive power lines or hydraulic control lines. The safety will be taken care of also off-grid, fully digitized. Should cabling of instrument signals be damaged, the system of tomorrow will still be up to par with the Safety Integrity Levels needed. New super-capacitors with an extra dense storage capacity being developed in partnership between the industry and the University of southeast Norway combined with an extremely low energy consuming actuation system with the fastest failsafe mechanism ever will ensure safety in all modes of operation, even with all lines down or consumed by flames. The paper aims to show how the technology works and underline why it will take a place in the future of well control and production.","PeriodicalId":10965,"journal":{"name":"Day 3 Thu, September 23, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80835961","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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