Carbon dioxide (CO2) capture, utilization, and storage is the best option for mitigating atmospheric emissions of CO2 and thereby controlling the greenhouse gas concentrations in the atmosphere. Despite the benefits, there have been a limited number of projects solely for CO2 sequestration being implemented. The industry is well-versed in gas injection in reservoir formation for pressure maintenance and improving oil recovery. However, there are striking differences between the injection of CO2 into depleted hydrocarbon reservoirs and the engineered storage of CO2. The differences and challenges are compounded when the storage site is karstified carbonate in offshore and bulk storage volume. It is paramount to know upfront that CO2 can be stored at a potential storage site and demonstrate that the site can meet required storage performance safety criteria. Comprehensive screening for site selection has been carried out for suitable CO2 storage sites in offshore Sarawak, Malaysia using geographical, geological, geophysical, geomechanical and reservoir engineering data and techniques for evaluating storage volume, container architecture, pressure, and temperature conditions. The site-specific input data are integrated into static and dynamic models for characterization and generating performance scenarios of the site. In addition, the geochemical interaction of CO2 with reservoir rock has been studied to understand possible changes that may occur during/after injection and their impact on injection processes/mechanisms. Novel 3-way coupled modelling of dynamic-geochemistry-geomechanics processes were carried out to study long-term dynamic behaviour and fate of CO2 in the formation. The 3-way coupled modelling helped to understand the likely state of injectant in future and the storage mechanism, i.e., structural, solubility, residual, and mineralized trapping. It also provided realistic storage capacity estimation, incorporating reservoir compaction and porosity/permeability changes. The study indicates deficient localized plastic shear strain in overburden flank fault whilst all the other flaws remained stable. The potential threat of leakage is minimal as target injection pressure is set at initial reservoir pressure, which is much lower than caprock breaching pressure during injection. Furthermore, it was found that the geochemical reaction impact is shallow and localized at the top of the reservoir, making the storage safe in the long term. The integrity of existing wells was evaluated for potential leakage and planned for a proper mitigation plan. Comprehensive measurement, monitoring, and verification (MMV) were also designed using state-of-art tools and dynamic simulation results. The understanding gaps are closed with additional technical work to improve technologies application and decrease the uncertainties. A comprehensive study for offshore CO2 storage projects identifying critical impacting elements is crucial for estimation, inje
{"title":"A Toolkit for Carbon Capture and Storage in Offshore Depleted Gas Field","authors":"R. Tewari, C. Tan, M. Sedaralit","doi":"10.4043/31651-ms","DOIUrl":"https://doi.org/10.4043/31651-ms","url":null,"abstract":"\u0000 Carbon dioxide (CO2) capture, utilization, and storage is the best option for mitigating atmospheric emissions of CO2 and thereby controlling the greenhouse gas concentrations in the atmosphere. Despite the benefits, there have been a limited number of projects solely for CO2 sequestration being implemented. The industry is well-versed in gas injection in reservoir formation for pressure maintenance and improving oil recovery. However, there are striking differences between the injection of CO2 into depleted hydrocarbon reservoirs and the engineered storage of CO2. The differences and challenges are compounded when the storage site is karstified carbonate in offshore and bulk storage volume.\u0000 It is paramount to know upfront that CO2 can be stored at a potential storage site and demonstrate that the site can meet required storage performance safety criteria. Comprehensive screening for site selection has been carried out for suitable CO2 storage sites in offshore Sarawak, Malaysia using geographical, geological, geophysical, geomechanical and reservoir engineering data and techniques for evaluating storage volume, container architecture, pressure, and temperature conditions. The site-specific input data are integrated into static and dynamic models for characterization and generating performance scenarios of the site. In addition, the geochemical interaction of CO2 with reservoir rock has been studied to understand possible changes that may occur during/after injection and their impact on injection processes/mechanisms. Novel 3-way coupled modelling of dynamic-geochemistry-geomechanics processes were carried out to study long-term dynamic behaviour and fate of CO2 in the formation.\u0000 The 3-way coupled modelling helped to understand the likely state of injectant in future and the storage mechanism, i.e., structural, solubility, residual, and mineralized trapping. It also provided realistic storage capacity estimation, incorporating reservoir compaction and porosity/permeability changes. The study indicates deficient localized plastic shear strain in overburden flank fault whilst all the other flaws remained stable. The potential threat of leakage is minimal as target injection pressure is set at initial reservoir pressure, which is much lower than caprock breaching pressure during injection. Furthermore, it was found that the geochemical reaction impact is shallow and localized at the top of the reservoir, making the storage safe in the long term. The integrity of existing wells was evaluated for potential leakage and planned for a proper mitigation plan. Comprehensive measurement, monitoring, and verification (MMV) were also designed using state-of-art tools and dynamic simulation results. The understanding gaps are closed with additional technical work to improve technologies application and decrease the uncertainties.\u0000 A comprehensive study for offshore CO2 storage projects identifying critical impacting elements is crucial for estimation, inje","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"66 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80733835","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}
Ilias Soultanias, J. Sarvaiya, Aditya Bose, Panos Koutsourakis, Georgios Plevrakis
With climate change as a transformative catalyst, the Offshore sector, which has long been a main pillar of the energy industry, is expected to undergo significant transformation in the coming years. Unique challenges associated with the fossil fuel products and their environmental impact are expected. Despite the limited and localized regulatory framework, the main drive towards sustainability is coming from the financing sector and other key external stakeholders. Embracing sustainability pertains to a series of initiatives and actions around: Benchmarking environmental footprint of the assets and operationsDesign, Engineering, Procurement & Construction and subsequent Operations following certain sustainability criteriaIntroducing Environmental, Social and Governance reporting This article elaborates on the structured approach of Sustainability principles and initiatives on the highly carbon intense offshore oil & gas industry.
{"title":"Sustainability Aspects for the Offshore Sector - Bridging Operations, Carbon Accounting and Esg Principles","authors":"Ilias Soultanias, J. Sarvaiya, Aditya Bose, Panos Koutsourakis, Georgios Plevrakis","doi":"10.4043/31681-ms","DOIUrl":"https://doi.org/10.4043/31681-ms","url":null,"abstract":"\u0000 With climate change as a transformative catalyst, the Offshore sector, which has long been a main pillar of the energy industry, is expected to undergo significant transformation in the coming years. Unique challenges associated with the fossil fuel products and their environmental impact are expected. Despite the limited and localized regulatory framework, the main drive towards sustainability is coming from the financing sector and other key external stakeholders.\u0000 Embracing sustainability pertains to a series of initiatives and actions around: Benchmarking environmental footprint of the assets and operationsDesign, Engineering, Procurement & Construction and subsequent Operations following certain sustainability criteriaIntroducing Environmental, Social and Governance reporting\u0000 This article elaborates on the structured approach of Sustainability principles and initiatives on the highly carbon intense offshore oil & gas industry.","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"72 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86134324","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}
Loss Of Primary Containment (LOPC) due to hydrocarbon leakage from bolted flange joint has always been one of the main issues that leads to catastrophic fire and explosion in operating platforms and plants. Oil and gas companies have been putting many efforts to reduce Health, Safety and Environment (HSE) incidences due to the flange joint integrity issues. PETRONAS, which operates many oil and gas platforms, has also made series of improvement in lesson learnt and enhanced best practices to find a wholesome solution to achieve sustainable zero hydrocarbon leak from bolted flange joint. Loss Of Primary Containment (LOPC) due to hydrocarbon leakage from bolted flange joint is one of major concerns in oil and gas industry, which may cause catastrophic fire and explosion at platforms and plants. Bolted Flange Joint Integrity (BFJI) digitalization program is designed to emphasize on end-to-end digital solution addressing three main important aspects towards sustainable flange leak free operation that included correct design and specification, good quality flange joint components and correct work execution.
{"title":"Bolted Flange Joint Integrity Digitalization Programme for Sustainable Flange Leak Free Operation","authors":"S. Saad, Alzakri Ekhwan, Syed M Hafiz Al-Idrus","doi":"10.4043/31587-ms","DOIUrl":"https://doi.org/10.4043/31587-ms","url":null,"abstract":"\u0000 Loss Of Primary Containment (LOPC) due to hydrocarbon leakage from bolted flange joint has always been one of the main issues that leads to catastrophic fire and explosion in operating platforms and plants. Oil and gas companies have been putting many efforts to reduce Health, Safety and Environment (HSE) incidences due to the flange joint integrity issues. PETRONAS, which operates many oil and gas platforms, has also made series of improvement in lesson learnt and enhanced best practices to find a wholesome solution to achieve sustainable zero hydrocarbon leak from bolted flange joint. Loss Of Primary Containment (LOPC) due to hydrocarbon leakage from bolted flange joint is one of major concerns in oil and gas industry, which may cause catastrophic fire and explosion at platforms and plants. Bolted Flange Joint Integrity (BFJI) digitalization program is designed to emphasize on end-to-end digital solution addressing three main important aspects towards sustainable flange leak free operation that included correct design and specification, good quality flange joint components and correct work execution.","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82169345","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
This study presents the coreflooding experiments to evaluate the performance of PAM/PEI polymer gels as conformance control agent in porous media. The experiments were designed to investigate the effectiveness of PAM/PEI polymer gels to block a high permeability zone and to divert water to low permeability zone. The work is based on four relevant elements that determine the suitability of a gel to mitigate excessive water production in a high temperature and high pressure conditions. They are adequate gelation time to achieve the target zone, reducing permeability to water, applicable injectivity, and long-term thermal stability. Two different coreflooding schemes were performed, which are coreflooding without crossflow using native sandstone, and coreflooding with crossflow using composite core that has permeability contrast. Native and composite cores represent homogeneous and heterogeneous reservoirs, respectively. Four different set of gelants, which are; 1) pure PAM/PEI polymer gelant; 2) PAM/PEI polymer gelant with NH4O; 3) PAM/PEI polymer gelant with NH4O at high salinity; and 4) Polymer gelant in high salinity and NH4Cl reinforced with SiO2 nanoparticles (NP), were prepared and injected into the cores. The selected mixture of gelants are sufficient to represent the effect of salinity, NH4Cl as retarder and solid nanoparticles on the gel in porous media. The pressure drop is an indication of the gel strength. Higher pressure drop signifies good gel strength. The highest pressure drop can be observed in the core treated with silica NP reinforced polymer gel. Compared to the gel without silica NP, the pressure drop during waterflooding post gel treatment can rise up to 1500 psi. On the oil recovery, highest recovery is established for core treated with reinforced polymer gel. Additional 24% of the trapped oil was recovered after treatment. It signifies the effectiveness of polymer gel with silica NP to divert the flow of water into where trapped oil is located. Good gel performance can be visualized through the dye stain on the surface of the core cut. When brine is injected, the dye stain will be left at the water flow path. For the core treated with reinforced gel, the dye stain is only spotted at the inlet of the core. It can be assumed that rigid gel is able to divert water to low permeability zone before water reaches further surface. The different mixture of PAM/PEI polymer gels were assessed in native and composite sandstone cores at high temperature and pressure. Results showed that PAM/PEI polymer gel reinforced with solid silica NP has proved to provide satisfactory gel strength to divert water flow, thus effective to recover more oil. Strengthening gel by addition of solid particles could be the remedy for the weakened polymer gel.
{"title":"Coreflooding Experiments on PAM/PEI Polymer Gel for Water Control in High-Temperature and High-Pressure Conditions: With and Without Crossflow Effect","authors":"Zulhelmi Amir, Ismail Mohd Saaid, B. Mohamed Jan","doi":"10.4043/31667-ms","DOIUrl":"https://doi.org/10.4043/31667-ms","url":null,"abstract":"\u0000 This study presents the coreflooding experiments to evaluate the performance of PAM/PEI polymer gels as conformance control agent in porous media. The experiments were designed to investigate the effectiveness of PAM/PEI polymer gels to block a high permeability zone and to divert water to low permeability zone. The work is based on four relevant elements that determine the suitability of a gel to mitigate excessive water production in a high temperature and high pressure conditions. They are adequate gelation time to achieve the target zone, reducing permeability to water, applicable injectivity, and long-term thermal stability. Two different coreflooding schemes were performed, which are coreflooding without crossflow using native sandstone, and coreflooding with crossflow using composite core that has permeability contrast. Native and composite cores represent homogeneous and heterogeneous reservoirs, respectively. Four different set of gelants, which are; 1) pure PAM/PEI polymer gelant; 2) PAM/PEI polymer gelant with NH4O; 3) PAM/PEI polymer gelant with NH4O at high salinity; and 4) Polymer gelant in high salinity and NH4Cl reinforced with SiO2 nanoparticles (NP), were prepared and injected into the cores. The selected mixture of gelants are sufficient to represent the effect of salinity, NH4Cl as retarder and solid nanoparticles on the gel in porous media. The pressure drop is an indication of the gel strength. Higher pressure drop signifies good gel strength. The highest pressure drop can be observed in the core treated with silica NP reinforced polymer gel. Compared to the gel without silica NP, the pressure drop during waterflooding post gel treatment can rise up to 1500 psi. On the oil recovery, highest recovery is established for core treated with reinforced polymer gel. Additional 24% of the trapped oil was recovered after treatment. It signifies the effectiveness of polymer gel with silica NP to divert the flow of water into where trapped oil is located. Good gel performance can be visualized through the dye stain on the surface of the core cut. When brine is injected, the dye stain will be left at the water flow path. For the core treated with reinforced gel, the dye stain is only spotted at the inlet of the core. It can be assumed that rigid gel is able to divert water to low permeability zone before water reaches further surface. The different mixture of PAM/PEI polymer gels were assessed in native and composite sandstone cores at high temperature and pressure. Results showed that PAM/PEI polymer gel reinforced with solid silica NP has proved to provide satisfactory gel strength to divert water flow, thus effective to recover more oil. Strengthening gel by addition of solid particles could be the remedy for the weakened polymer gel.","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"12 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74298435","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}
Over the years, laboratory studies and a limited number of field trials have demonstrated the potential of enhancing oil recovery using controlled-salinity water flooding. The injected brine composition is one of the promising techniques that could alter the wettability of carbonate rocks by changing the concentration of the potential determining ions (PDIs), specifically Ca2+, Mg2+, and SO42− ions. In this study, a comprehensive experimental study was conducted to investigate the rock-fluid and fluid-fluid interactions at rock-water and oil-water interfaces. The first step of the study was to measure the interfacial tension (IFT) using the spinning-drop tensiometer and study the dynamic behavior of the oil-water interactions. The zeta potential of carbonate rock samples was then measured using a specially-designed zeta potentiometer capable of utilizing the whole core plug, rather than the pulverized samples. The streaming potential technique was used for the zeta potential measurements and the experiments were conducted under different modified brine composition and rock saturation conditions. Subsequently, wettability alteration experiments were conducted using a specially designed high-pressure high-temperature (HP/HT) cell. The IFT measurements showed an increasing trend as salinity decreases, clarifying that rock-water interactions are more dominant over oil-water interactions. Results of the zeta potential experiments showed a clear trend of yielding more negative values as the seawater gradually diluted down to 1%dSW, due to the expansion of the electrical double layer. On the other hand, when the brine composition was modified, the increase of the PDIs (Ca2+ and Mg2+) did not have as much impact on zeta potential as the SO42− ions. In the wettability alteration experiments, both diluted and composition-modified brine generated a higher imbibition rate, resulting in a higher total oil production when compared with the experiments using the seawater. Furthermore, the wettability alteration of the rock surface trended more towards water-wetness conditions, as inferred from the contact angle measurements. The measurement of zeta potential before and after wettability alteration tests showed that the zeta potential value became less negative after the experiment, which suggested the expulsion of oil from the rock. This was further verified by the measurements of zeta potential for the unsaturated rock and saturated rock with brine and oil. The findings from this study would provide a better understanding of the rock-fluid and fluid-fluid interactions during controlled-salinity water flooding, which will benefit future studies in this area.
{"title":"Understanding the Interactions at Rock-Water and Oil-Water Interfaces during Controlled-Salinity Water Flooding","authors":"A. Belhaj, N. Singh, H. Sarma","doi":"10.4043/31656-ms","DOIUrl":"https://doi.org/10.4043/31656-ms","url":null,"abstract":"Over the years, laboratory studies and a limited number of field trials have demonstrated the potential of enhancing oil recovery using controlled-salinity water flooding. The injected brine composition is one of the promising techniques that could alter the wettability of carbonate rocks by changing the concentration of the potential determining ions (PDIs), specifically Ca2+, Mg2+, and SO42− ions. In this study, a comprehensive experimental study was conducted to investigate the rock-fluid and fluid-fluid interactions at rock-water and oil-water interfaces. The first step of the study was to measure the interfacial tension (IFT) using the spinning-drop tensiometer and study the dynamic behavior of the oil-water interactions. The zeta potential of carbonate rock samples was then measured using a specially-designed zeta potentiometer capable of utilizing the whole core plug, rather than the pulverized samples. The streaming potential technique was used for the zeta potential measurements and the experiments were conducted under different modified brine composition and rock saturation conditions. Subsequently, wettability alteration experiments were conducted using a specially designed high-pressure high-temperature (HP/HT) cell. The IFT measurements showed an increasing trend as salinity decreases, clarifying that rock-water interactions are more dominant over oil-water interactions. Results of the zeta potential experiments showed a clear trend of yielding more negative values as the seawater gradually diluted down to 1%dSW, due to the expansion of the electrical double layer. On the other hand, when the brine composition was modified, the increase of the PDIs (Ca2+ and Mg2+) did not have as much impact on zeta potential as the SO42− ions. In the wettability alteration experiments, both diluted and composition-modified brine generated a higher imbibition rate, resulting in a higher total oil production when compared with the experiments using the seawater. Furthermore, the wettability alteration of the rock surface trended more towards water-wetness conditions, as inferred from the contact angle measurements. The measurement of zeta potential before and after wettability alteration tests showed that the zeta potential value became less negative after the experiment, which suggested the expulsion of oil from the rock. This was further verified by the measurements of zeta potential for the unsaturated rock and saturated rock with brine and oil. The findings from this study would provide a better understanding of the rock-fluid and fluid-fluid interactions during controlled-salinity water flooding, which will benefit future studies in this area.","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"10 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83390201","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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