Obiora Nwosu, Olugbenga Daodu, Basil Ogbunude, C. Emelle, E. Nnanna, J. Emesi
MERO-006T is an oil development well that was drilled and completed in the Q2100X reservoir. The well came into production in March 1988 and has been plagued with incessant wax build up leading to loss of oil production several times over a period of 17years. Several wax cutting activities have been carried out to restore production in the well, however due to the frequency of wax build up leading to loss of revenue and the difficulty of the swamp terrain where the well is located, it became pertinent to adopt a more optimal, cost effective and long-term approach to address the frequent deferment caused by wax build up. Research indicates that a wax inhibition tool (Silver HAWG) can be deployed in the well to address wax build up issue though historical deployment in some wells have not been very effective due to suboptimal installation depths in these wells. Hence, it became pertinent to determine the optimal depth for installation of the wax inhibition tool in MERO-006T. This paper highlights the thermodynamic modelling approach adopted to determine the Wax Appearance Temperature in MERO-006T, the well modelling approach to estimate the depth which wax formation would occur and the optimal depth to place the wax inhibition tool based on lifecycle production expectations from the well. Installation of the Silver HAWG is expected to restore ca. 500 bopd, improve well availability by 30% and avoid biannual costs of ca. $2mln associated with repeated wax treatment in the well.
{"title":"Prediction and Prevention of Wax Deposition in MERO-006T: A Thermodynamic Modelling Approach","authors":"Obiora Nwosu, Olugbenga Daodu, Basil Ogbunude, C. Emelle, E. Nnanna, J. Emesi","doi":"10.2118/211943-ms","DOIUrl":"https://doi.org/10.2118/211943-ms","url":null,"abstract":"\u0000 MERO-006T is an oil development well that was drilled and completed in the Q2100X reservoir. The well came into production in March 1988 and has been plagued with incessant wax build up leading to loss of oil production several times over a period of 17years.\u0000 Several wax cutting activities have been carried out to restore production in the well, however due to the frequency of wax build up leading to loss of revenue and the difficulty of the swamp terrain where the well is located, it became pertinent to adopt a more optimal, cost effective and long-term approach to address the frequent deferment caused by wax build up.\u0000 Research indicates that a wax inhibition tool (Silver HAWG) can be deployed in the well to address wax build up issue though historical deployment in some wells have not been very effective due to suboptimal installation depths in these wells. Hence, it became pertinent to determine the optimal depth for installation of the wax inhibition tool in MERO-006T.\u0000 This paper highlights the thermodynamic modelling approach adopted to determine the Wax Appearance Temperature in MERO-006T, the well modelling approach to estimate the depth which wax formation would occur and the optimal depth to place the wax inhibition tool based on lifecycle production expectations from the well. Installation of the Silver HAWG is expected to restore ca. 500 bopd, improve well availability by 30% and avoid biannual costs of ca. $2mln associated with repeated wax treatment in the well.","PeriodicalId":399294,"journal":{"name":"Day 2 Tue, August 02, 2022","volume":"15 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122629310","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 investigates the susceptibility of the 'JXT' field, onshore Niger Delta to ground subsidence as an after effect of oil and gas production. Logs from two wells in the field were utilized for this study, Gassmann's model and the modified Hashin-Shtrikman-Walpole model for compressibility analysis were adopted. The results from Gassmann's model range from 0.06GPa-1 to 0.13GPa-1, while results from the modified Hashin-Shtrikman-Walpole bounds for compressibility range from 0.04GPa-1 to 3GPa-1. To further evaluate the susceptibility of the field to ground subsidence, some important elastic parameters were estimated. Results show young modulus (20.5-27.5GPa), bulk modulus (21.3-25.3GPa), shear modulus (8.01-11.2GPa), and Poisson ratio (0.23-0.28). Generally, these results indicate that the study area is less susceptible to ground subsidence and there is little risk of flooding and submergence which can be hazardous to oil and gas production
{"title":"Application of Gassmann's Model and the Modified Hashin-Shtrikman-Walpole Model in Land Subsidence Susceptibility Studies in the Jxt Field, Niger Delta","authors":"Chukwudi Idowu, B. Ojo","doi":"10.2118/211960-ms","DOIUrl":"https://doi.org/10.2118/211960-ms","url":null,"abstract":"\u0000 This paper investigates the susceptibility of the 'JXT' field, onshore Niger Delta to ground subsidence as an after effect of oil and gas production. Logs from two wells in the field were utilized for this study, Gassmann's model and the modified Hashin-Shtrikman-Walpole model for compressibility analysis were adopted. The results from Gassmann's model range from 0.06GPa-1 to 0.13GPa-1, while results from the modified Hashin-Shtrikman-Walpole bounds for compressibility range from 0.04GPa-1 to 3GPa-1. To further evaluate the susceptibility of the field to ground subsidence, some important elastic parameters were estimated. Results show young modulus (20.5-27.5GPa), bulk modulus (21.3-25.3GPa), shear modulus (8.01-11.2GPa), and Poisson ratio (0.23-0.28). Generally, these results indicate that the study area is less susceptible to ground subsidence and there is little risk of flooding and submergence which can be hazardous to oil and gas production","PeriodicalId":399294,"journal":{"name":"Day 2 Tue, August 02, 2022","volume":"19 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128206161","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}
Adebimpe Oyeyele, Camilla Junaid, Kawu Idris-Idah, Daniel Olomolaiye, Eretoru Robert
In this work, a case study of a modular crude oil refinery is carried out. Located in Imo State, Nigeria, it is the first refinery to simultaneously produce four (4) petroleum products - Naphtha, Kerosene, Automotive Gas Oil (AGO) (i.e., Diesel) and Heavy Pour Fuel Oil (HPFO), that have constantly met the requirements of the Nigerian Department of Petroleum Resources (DPR). The refinery is situated beside the Ibigwe Marginal Field from which it obtains its crude oil; it represents perhaps the personification of efficiency in maximizing value from petroleum resources. Numerous lessons exist for prospective modular refiners. The paper aims to identify optimal process conditions and discuss a data-focused strategy utilized in ensuring optimal distillation column parameters required to achieve the production of "on-spec" (that is, meeting the desired regulatory/client quality specifications) distillates. The set points of temperatures and pressures for the distillation and stripping of each product were examined, while assessing the impact of changes in feed stock properties, product specifications or ambient conditions and the adjustments that needed to be made to process conditions. Some examples of the concerned characteristics of the product required to meet specification are API Gravity, Flash point and Pour Point. The reflux temperature, petroleum products draw rate, etc. are few variables to be appropriately manipulated. Strategies were developed and implemented for all stages of the refinery’s development – preliminary ones being the Design stage and Construction stage, with the ongoing one being the operation stage. Literature alludes to refiners categorizing "meeting specifications" as a potential problem. For example, you have now obtained "on spec" kerosene, what quantity of "on spec" diesel is left? In this paper, the technical journey to meeting DPR requirements is narrated, aiming to transfer knowledge and further develop the nation’s ability to meet its energy needs.
{"title":"Optimising Process Conditions to Obtain Distillate Properties Within Regional Specifications","authors":"Adebimpe Oyeyele, Camilla Junaid, Kawu Idris-Idah, Daniel Olomolaiye, Eretoru Robert","doi":"10.2118/211992-ms","DOIUrl":"https://doi.org/10.2118/211992-ms","url":null,"abstract":"\u0000 In this work, a case study of a modular crude oil refinery is carried out. Located in Imo State, Nigeria, it is the first refinery to simultaneously produce four (4) petroleum products - Naphtha, Kerosene, Automotive Gas Oil (AGO) (i.e., Diesel) and Heavy Pour Fuel Oil (HPFO), that have constantly met the requirements of the Nigerian Department of Petroleum Resources (DPR). The refinery is situated beside the Ibigwe Marginal Field from which it obtains its crude oil; it represents perhaps the personification of efficiency in maximizing value from petroleum resources. Numerous lessons exist for prospective modular refiners.\u0000 The paper aims to identify optimal process conditions and discuss a data-focused strategy utilized in ensuring optimal distillation column parameters required to achieve the production of \"on-spec\" (that is, meeting the desired regulatory/client quality specifications) distillates. The set points of temperatures and pressures for the distillation and stripping of each product were examined, while assessing the impact of changes in feed stock properties, product specifications or ambient conditions and the adjustments that needed to be made to process conditions. Some examples of the concerned characteristics of the product required to meet specification are API Gravity, Flash point and Pour Point. The reflux temperature, petroleum products draw rate, etc. are few variables to be appropriately manipulated. Strategies were developed and implemented for all stages of the refinery’s development – preliminary ones being the Design stage and Construction stage, with the ongoing one being the operation stage.\u0000 Literature alludes to refiners categorizing \"meeting specifications\" as a potential problem. For example, you have now obtained \"on spec\" kerosene, what quantity of \"on spec\" diesel is left? In this paper, the technical journey to meeting DPR requirements is narrated, aiming to transfer knowledge and further develop the nation’s ability to meet its energy needs.","PeriodicalId":399294,"journal":{"name":"Day 2 Tue, August 02, 2022","volume":"7 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129522250","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 2015, the United Nations General Assembly set up the Sustainable Development Goals as a follow up on the Millennium Development Goals and a masterplan to attain a better and more sustainable world by the year 2030. One of these goals (SDG 7), seeks to achieve affordable and clean energy for all the world's population by the year 2030. As a result, global efforts are being made to reduce greenhouse gas (GHG) emissions to limit pollution as well as enhance the development of renewable energies such as solar, wind, hydrothermal amongst others into the worlds energy system. The oil and gas industry has played a vital role in meeting the world's energy demand to date. 60% of world energy consumption was supplied by the oil and gas industry for year 2020 and as this demand keeps rising, the industry will continue to play this vital role in powering and enabling industries. Therefore, even as the world clamours for a shift from a world powered by fossil fuels to one sustained by green energy, the success of this global energy transition would still be heavily dependent on the drivers and players of fossil fuel technology. As such, there is a need for the African oil and gas industry to realize that although it may no longer be business as usual, this shift presents an opportunity for the industry to contribute to the emerging energy mix as well as correct negative perceptions the general public might have of the industry. To remain relevant, companies must adapt, invest in renewable energy research and development and build on existing technology. This paper explores and gives insight into the ways oil and gas companies have begun harnessing renewable energy in their operations, challenges being faced to reduce carbon emissions to achieve net zero and how hydrocarbon production operations can be done in a more environmentally safe manner. To strengthen this cause, stakeholders, policy makers and engineers in the African clime must investigate the dynamics, parallels and interdependency between conventional and renewable energy, to be strategically positioned to play a key role in the transition to a more sustainable future.
{"title":"Assessment of the Prospect and Challenges of the African Oil and Gas Industry in Harnessing Energy for a More Sustainable World","authors":"Jesujoba Olubodun","doi":"10.2118/211937-ms","DOIUrl":"https://doi.org/10.2118/211937-ms","url":null,"abstract":"\u0000 In 2015, the United Nations General Assembly set up the Sustainable Development Goals as a follow up on the Millennium Development Goals and a masterplan to attain a better and more sustainable world by the year 2030. One of these goals (SDG 7), seeks to achieve affordable and clean energy for all the world's population by the year 2030. As a result, global efforts are being made to reduce greenhouse gas (GHG) emissions to limit pollution as well as enhance the development of renewable energies such as solar, wind, hydrothermal amongst others into the worlds energy system.\u0000 The oil and gas industry has played a vital role in meeting the world's energy demand to date. 60% of world energy consumption was supplied by the oil and gas industry for year 2020 and as this demand keeps rising, the industry will continue to play this vital role in powering and enabling industries. Therefore, even as the world clamours for a shift from a world powered by fossil fuels to one sustained by green energy, the success of this global energy transition would still be heavily dependent on the drivers and players of fossil fuel technology. As such, there is a need for the African oil and gas industry to realize that although it may no longer be business as usual, this shift presents an opportunity for the industry to contribute to the emerging energy mix as well as correct negative perceptions the general public might have of the industry. To remain relevant, companies must adapt, invest in renewable energy research and development and build on existing technology.\u0000 This paper explores and gives insight into the ways oil and gas companies have begun harnessing renewable energy in their operations, challenges being faced to reduce carbon emissions to achieve net zero and how hydrocarbon production operations can be done in a more environmentally safe manner. To strengthen this cause, stakeholders, policy makers and engineers in the African clime must investigate the dynamics, parallels and interdependency between conventional and renewable energy, to be strategically positioned to play a key role in the transition to a more sustainable future.","PeriodicalId":399294,"journal":{"name":"Day 2 Tue, August 02, 2022","volume":"60 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133921670","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}
O. I. Ajayi, Sodiq Adejuwon Kehinde, U. Akpan, D. Odesa
During drilling operations, one of the key parameters keenly monitored and measured is the Non-Productive Time (NPT). It is usually desired to be kept as minimal as possible due to its significant contribution to the entire well construction cost. In some instances, some of the factors responsible cannot be controlled such as bad weather conditions or occurrence of natural disasters. However, industry experience shows that a significant chunk of most NPT recorded can be avoided and mitigated with adequate planning, monitoring and prompt decision-making. In order to ensure sustainable oil production amidst the present economic situation of fluctuating crude oil prices occasioned by the imminent energy transition and other related factors, the costs associated with development and production of hydrocarbon assets will require prudent management by eliminating or reducing NPTs. This paper aims to illustrate some of the best in-class operational procedures and actions undertaken by the drilling operations team of a producing company for significant reduction of NPT spanning across seven (7) wells in two (2) of its producing fields. Information from structured daily operations reports were extracted and analyzed with significant focus on the time sheets and contributing factors to Non-Productive Time. Further attempts were made to identify the major contributors and the most efficient processes to eliminate their occurrences. The analysis shows an average of about thirteen percent from the first well drilled in 2018 to the most recent one drilled in 2021. This translates to about USD5.4 million in NPT cost equivalent over the span of the seven (7) wells. The prevalent drilling operational challenges were found to be related to host community issues, location preparation, statutory regulatory compliance issues, logistics, weather conditions, crew competency, well-bore instability, and most prevalently rig equipment failures etc. The data analysis showed a consistent decrease in NPTs for these factors, primarily due to deliberate and concise project planning and execution. The results from these analyses can therefore be used as a framework to improve current drilling practices, in order to achieve significant well construction cost savings and further support the need for sustainable oil production. However, it is important to ensure quality data gathering and structure by insisting on identifying and recording all the NPT-related issues. This will allow prompt forecasting of drilling operational challenges as well as proactively taking concrete steps to mitigating them.
{"title":"Reducing NPT Amidst Fluctuating Crude Oil Prices: Using Data Analysis to Investigate Well Construction Cost","authors":"O. I. Ajayi, Sodiq Adejuwon Kehinde, U. Akpan, D. Odesa","doi":"10.2118/212030-ms","DOIUrl":"https://doi.org/10.2118/212030-ms","url":null,"abstract":"\u0000 During drilling operations, one of the key parameters keenly monitored and measured is the Non-Productive Time (NPT). It is usually desired to be kept as minimal as possible due to its significant contribution to the entire well construction cost. In some instances, some of the factors responsible cannot be controlled such as bad weather conditions or occurrence of natural disasters. However, industry experience shows that a significant chunk of most NPT recorded can be avoided and mitigated with adequate planning, monitoring and prompt decision-making. In order to ensure sustainable oil production amidst the present economic situation of fluctuating crude oil prices occasioned by the imminent energy transition and other related factors, the costs associated with development and production of hydrocarbon assets will require prudent management by eliminating or reducing NPTs. This paper aims to illustrate some of the best in-class operational procedures and actions undertaken by the drilling operations team of a producing company for significant reduction of NPT spanning across seven (7) wells in two (2) of its producing fields. Information from structured daily operations reports were extracted and analyzed with significant focus on the time sheets and contributing factors to Non-Productive Time. Further attempts were made to identify the major contributors and the most efficient processes to eliminate their occurrences. The analysis shows an average of about thirteen percent from the first well drilled in 2018 to the most recent one drilled in 2021. This translates to about USD5.4 million in NPT cost equivalent over the span of the seven (7) wells. The prevalent drilling operational challenges were found to be related to host community issues, location preparation, statutory regulatory compliance issues, logistics, weather conditions, crew competency, well-bore instability, and most prevalently rig equipment failures etc. The data analysis showed a consistent decrease in NPTs for these factors, primarily due to deliberate and concise project planning and execution. The results from these analyses can therefore be used as a framework to improve current drilling practices, in order to achieve significant well construction cost savings and further support the need for sustainable oil production. However, it is important to ensure quality data gathering and structure by insisting on identifying and recording all the NPT-related issues. This will allow prompt forecasting of drilling operational challenges as well as proactively taking concrete steps to mitigating them.","PeriodicalId":399294,"journal":{"name":"Day 2 Tue, August 02, 2022","volume":"71 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127083828","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}
Pearl Isabellah Murungi, A. Sulaimon, Oscar Ssembatya, P. Nwankwo
Preventing and mitigating corrosion problems can be very challenging due to technical considerations and prohibitive economic implications. It is thus imperative to arrest the escalating corrosion rates and impede the deterioration effects of corrosion with versatile remedies. In this review, previous research efforts on the application of plant-derived polysaccharides as potential inhibitors of metal corrosion in various aggressive media are studied. The deployment of corrosion inhibitors has proven to be an outstanding solution to prolonging the lifespan of metals. However, the most applied inhibitors such as the inorganic and some organic compounds are prohibitively expensive, hazardous, and toxic. These limiting factors have stimulated interest in more research into greener and less toxic natural alternatives. Considering the success of synthetic polymers for corrosion inhibition, a wide range of plants with high natural polysaccharide content have been evaluated to determine their effectiveness as biodegradable, renewable, and more economical corrosion inhibitors. Studies generally show that natural polysaccharides exhibit over 90% efficiency for corrosion inhibition with appreciable adsorption on the metal surface. Modification and grafting of the plant polysaccharides to enhance their inhibition efficiencies and to make them more desirable are currently being investigated. Such bio-inspired polymeric molecules thus have invaluable significance as potential alternatives for the problematic corrosion inhibitors.
{"title":"A Review of Natural Polysaccharides as Corrosion Inhibitors: Recent Progress and Future Opportunities","authors":"Pearl Isabellah Murungi, A. Sulaimon, Oscar Ssembatya, P. Nwankwo","doi":"10.2118/211964-ms","DOIUrl":"https://doi.org/10.2118/211964-ms","url":null,"abstract":"\u0000 Preventing and mitigating corrosion problems can be very challenging due to technical considerations and prohibitive economic implications. It is thus imperative to arrest the escalating corrosion rates and impede the deterioration effects of corrosion with versatile remedies. In this review, previous research efforts on the application of plant-derived polysaccharides as potential inhibitors of metal corrosion in various aggressive media are studied. The deployment of corrosion inhibitors has proven to be an outstanding solution to prolonging the lifespan of metals. However, the most applied inhibitors such as the inorganic and some organic compounds are prohibitively expensive, hazardous, and toxic. These limiting factors have stimulated interest in more research into greener and less toxic natural alternatives. Considering the success of synthetic polymers for corrosion inhibition, a wide range of plants with high natural polysaccharide content have been evaluated to determine their effectiveness as biodegradable, renewable, and more economical corrosion inhibitors. Studies generally show that natural polysaccharides exhibit over 90% efficiency for corrosion inhibition with appreciable adsorption on the metal surface. Modification and grafting of the plant polysaccharides to enhance their inhibition efficiencies and to make them more desirable are currently being investigated. Such bio-inspired polymeric molecules thus have invaluable significance as potential alternatives for the problematic corrosion inhibitors.","PeriodicalId":399294,"journal":{"name":"Day 2 Tue, August 02, 2022","volume":"89 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127183388","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}
Interfacial tension (IFT) is an interfacial phenomenon that commonly exist between immiscible liquids such as oil and brine that are found in the hydrocarbon reservoirs. High IFT in combination with high capillary forces plays a fundamental role in residual oil saturation in the reservoir rock pores. The effects of enzyme and silica nanoparticles on crude oil-water and crude oil-brine interactions were investigated and presented in this study. The potential of individual application of enzyme and silica nanoparticles as well as the combination of both were explored under different salinity conditions. The results of this study showed that the application of silica nanoparticles did not significantly reduce oil-brine IFT under different salinity conditions investigated in this study, although the highest reduction was obtained with low salinity brine. The use of enzyme however significantly reduced oil-brine IFT under varied salinity conditions and better IFT reduction was obtained in brines relative to aqueous solution. Finally, the combination of enzyme with nanoparticles effected better IFT reduction than the application of either of them individually in aqueous solution and it also significantly reduced oil-brine IFT in all salinity conditions. This study is a novel investigation on the potential of enzyme-nanoparticles to modify oil-brine IFT and the result of this study is significant to the design and application of enzyme and nanoparticles enhanced oil recovery processes.
{"title":"Experimental Investigation on Effect of Enzyme and Nanoparticles on Oil-Brine Interfacial Tension","authors":"Tinuola Hannah, Oyinkepreye David","doi":"10.2118/211913-ms","DOIUrl":"https://doi.org/10.2118/211913-ms","url":null,"abstract":"\u0000 Interfacial tension (IFT) is an interfacial phenomenon that commonly exist between immiscible liquids such as oil and brine that are found in the hydrocarbon reservoirs. High IFT in combination with high capillary forces plays a fundamental role in residual oil saturation in the reservoir rock pores. The effects of enzyme and silica nanoparticles on crude oil-water and crude oil-brine interactions were investigated and presented in this study. The potential of individual application of enzyme and silica nanoparticles as well as the combination of both were explored under different salinity conditions. The results of this study showed that the application of silica nanoparticles did not significantly reduce oil-brine IFT under different salinity conditions investigated in this study, although the highest reduction was obtained with low salinity brine. The use of enzyme however significantly reduced oil-brine IFT under varied salinity conditions and better IFT reduction was obtained in brines relative to aqueous solution. Finally, the combination of enzyme with nanoparticles effected better IFT reduction than the application of either of them individually in aqueous solution and it also significantly reduced oil-brine IFT in all salinity conditions. This study is a novel investigation on the potential of enzyme-nanoparticles to modify oil-brine IFT and the result of this study is significant to the design and application of enzyme and nanoparticles enhanced oil recovery processes.","PeriodicalId":399294,"journal":{"name":"Day 2 Tue, August 02, 2022","volume":"79 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121058343","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}
It is usually an unnerving moment when a service tool is picked up, after a frac pack pumping operation with the goal to reach the "reverse position". The failure to establish this position could have significant undesirable consequences on the overall well objective, which could range from extensive fishing of the resulting stuck pipe to eventual loss of the well. It, therefore, becomes imperative for the completions planning team in collaboration with other relevant stakeholders to establish an "execution-friendly" reverse-out decision and communication protocol that will prevent a stuck situation. Agbami completions are mostly stacked frac pack with Intelligent Well Completion (IWC) capability to adequately control and monitor production. The first phase completion of the three-phased development was installed in 2007, while production commenced in 2008 [1]. A major consideration for the phased development campaign was to ensure lessons learned from one phase can be applied to the next. The 8-well Infill Drilling campaign was executed from 2017 to 2019 to capture un-swept oil and optimize production from the field. The Agbami frac service tools were successfully upgraded after the initial development phases and deployed on the infill campaign to mitigate the challenges encountered during the third phase frac pack installations. This upgrade, coupled with standardized processes, equipment, and procedures contributed to the improved frac pack installation performance recorded on the infill campaign. Despite the frac pack improvements, a near-miss on one of the completions could have resulted in a stuck service tool where an overpull of up to 160kips was required to move the service tool to reverse out excess proppant. It also took seven attempts and ∼105 kips overpull to move the shifter and close the FS2 fluid loss isolation valve. An investigation into this near-miss identified amongst other opportunities, a gap in the current communication protocol, and the need to improve the operations team's situational awareness of downhole conditions during pumping, at screen-out and at reverse-out. The team leveraged global initiatives on stuck service tool prevention and collaborated with service partners and the rig contractor to develop a fit-for-purpose reverse out and communication protocol. This protocol was successfully implemented in subsequent well completions. A "Frac Pack on Paper" meeting held with all relevant stakeholders: the rig crew; pumping and completion service companies; Chevron's Frac support group, and Chevron's completions and operations teams, to methodically go through the reverse-out and communication protocol which contributed immensely to the huge success achieved on the frac pack operations. The team's effective collaboration with service partners contributed to the ability to respond quickly to these challenges leading to continuous improvement in Agbami frac pack executions. This paper aims to discuss the Agbami stu
{"title":"Agbami Stuck Frac Pack Service Tool Prevention Measures","authors":"C. Elendu, Steve Njoku, I. Ojukwu","doi":"10.2118/211903-ms","DOIUrl":"https://doi.org/10.2118/211903-ms","url":null,"abstract":"\u0000 It is usually an unnerving moment when a service tool is picked up, after a frac pack pumping operation with the goal to reach the \"reverse position\". The failure to establish this position could have significant undesirable consequences on the overall well objective, which could range from extensive fishing of the resulting stuck pipe to eventual loss of the well. It, therefore, becomes imperative for the completions planning team in collaboration with other relevant stakeholders to establish an \"execution-friendly\" reverse-out decision and communication protocol that will prevent a stuck situation.\u0000 Agbami completions are mostly stacked frac pack with Intelligent Well Completion (IWC) capability to adequately control and monitor production. The first phase completion of the three-phased development was installed in 2007, while production commenced in 2008 [1]. A major consideration for the phased development campaign was to ensure lessons learned from one phase can be applied to the next. The 8-well Infill Drilling campaign was executed from 2017 to 2019 to capture un-swept oil and optimize production from the field. The Agbami frac service tools were successfully upgraded after the initial development phases and deployed on the infill campaign to mitigate the challenges encountered during the third phase frac pack installations. This upgrade, coupled with standardized processes, equipment, and procedures contributed to the improved frac pack installation performance recorded on the infill campaign.\u0000 Despite the frac pack improvements, a near-miss on one of the completions could have resulted in a stuck service tool where an overpull of up to 160kips was required to move the service tool to reverse out excess proppant. It also took seven attempts and ∼105 kips overpull to move the shifter and close the FS2 fluid loss isolation valve. An investigation into this near-miss identified amongst other opportunities, a gap in the current communication protocol, and the need to improve the operations team's situational awareness of downhole conditions during pumping, at screen-out and at reverse-out.\u0000 The team leveraged global initiatives on stuck service tool prevention and collaborated with service partners and the rig contractor to develop a fit-for-purpose reverse out and communication protocol. This protocol was successfully implemented in subsequent well completions. A \"Frac Pack on Paper\" meeting held with all relevant stakeholders: the rig crew; pumping and completion service companies; Chevron's Frac support group, and Chevron's completions and operations teams, to methodically go through the reverse-out and communication protocol which contributed immensely to the huge success achieved on the frac pack operations. The team's effective collaboration with service partners contributed to the ability to respond quickly to these challenges leading to continuous improvement in Agbami frac pack executions.\u0000 This paper aims to discuss the Agbami stu","PeriodicalId":399294,"journal":{"name":"Day 2 Tue, August 02, 2022","volume":"235 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125756888","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}
Reliable production forecasting of all fluid streams involved in hydrocarbon production has remained a perennial problem in the oil and gas industry. This paper presents the methodology and results of an improvement to the water forecasting approach adopted in the management of all the producing fields and reservoirs of OML-ZZZ located in the Niger Delta area of Nigeria. The main objective of our study was to identify and evaluate a means of achieving water/liquid forecast that is representative of field observed trends – a key input for the sizing of planned water dehydration facilities for our fields. Our study made use of an integrated production forecasting solution model with the associated engineering and geoscience data, which optimizes on oil production while forecasting the other fluid streams subject to defined system constraints. Improvement in water forecast was achieved through a review of the abandonment conditions of quit wells which have already reached their abandonment as analogues for producing wells being forecasted. Based on the review, we identified and applied recommended tranches of BSW conditions which have enabled better and more realistic forecasts of gross liquid and water production. The benefits of these improved forecasts include an increase in oil volumes and proper equipment/facilities sizing among others.
{"title":"OML-ZZZ: Water Production Forecasting Improvement","authors":"Raphael Agbehi, Ugochukwu Aboaja, Rotimi Osho","doi":"10.2118/212025-ms","DOIUrl":"https://doi.org/10.2118/212025-ms","url":null,"abstract":"\u0000 Reliable production forecasting of all fluid streams involved in hydrocarbon production has remained a perennial problem in the oil and gas industry. This paper presents the methodology and results of an improvement to the water forecasting approach adopted in the management of all the producing fields and reservoirs of OML-ZZZ located in the Niger Delta area of Nigeria. The main objective of our study was to identify and evaluate a means of achieving water/liquid forecast that is representative of field observed trends – a key input for the sizing of planned water dehydration facilities for our fields. Our study made use of an integrated production forecasting solution model with the associated engineering and geoscience data, which optimizes on oil production while forecasting the other fluid streams subject to defined system constraints. Improvement in water forecast was achieved through a review of the abandonment conditions of quit wells which have already reached their abandonment as analogues for producing wells being forecasted. Based on the review, we identified and applied recommended tranches of BSW conditions which have enabled better and more realistic forecasts of gross liquid and water production. The benefits of these improved forecasts include an increase in oil volumes and proper equipment/facilities sizing among others.","PeriodicalId":399294,"journal":{"name":"Day 2 Tue, August 02, 2022","volume":"46 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129404872","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}
Sand production is a pertinent issue in oil and gas well engineering and a major cause of concern for the production engineer. He can plan for it, or he can prepare for it, albeit he would rather have it nipped in the bud right from the well’s completion phase. Sand production is costly, reducing the lifetime and durability of pipelines and production facilities, inadvertently impacting the company’s balance sheet negatively and in some cases reducing the life and productivity of the well itself. This paper critically evaluates sand production in the Niger Delta, using the Ibigwe field operated by Waltersmith Petroman Oil Limited as a case study. It proffers optimal sand exclusion methods for wells in the Niger Delta by analysing various subsurface datasets and historical sand production from offset wells within the field. The subsurface datasets identified as relevant to this study include sonic transit time, depth of burial of zones of interest, particle size analysis, geomechanical data (specifically unconfined compressive stress logs), Rate of Penetration (ROP) and other data logs. Evaluating all relevant data to the subject is imperative as discovered during research; none of the datasets listed above can be analysed in isolation, rather interdependently. The selection of an optimal sand exclusion method consequently affects the deployment of an effective completion mechanism and as such, this endeavour should be carried out conscientiously.
{"title":"Selection of Optimal Sand Exclusion Methods for Wells in The Onshore Niger Delta: The Ibigwe Field Case Study","authors":"C. E. Chime, Ibinabo Greenson Kalio","doi":"10.2118/211983-ms","DOIUrl":"https://doi.org/10.2118/211983-ms","url":null,"abstract":"\u0000 Sand production is a pertinent issue in oil and gas well engineering and a major cause of concern for the production engineer. He can plan for it, or he can prepare for it, albeit he would rather have it nipped in the bud right from the well’s completion phase. Sand production is costly, reducing the lifetime and durability of pipelines and production facilities, inadvertently impacting the company’s balance sheet negatively and in some cases reducing the life and productivity of the well itself. This paper critically evaluates sand production in the Niger Delta, using the Ibigwe field operated by Waltersmith Petroman Oil Limited as a case study. It proffers optimal sand exclusion methods for wells in the Niger Delta by analysing various subsurface datasets and historical sand production from offset wells within the field. The subsurface datasets identified as relevant to this study include sonic transit time, depth of burial of zones of interest, particle size analysis, geomechanical data (specifically unconfined compressive stress logs), Rate of Penetration (ROP) and other data logs. Evaluating all relevant data to the subject is imperative as discovered during research; none of the datasets listed above can be analysed in isolation, rather interdependently. The selection of an optimal sand exclusion method consequently affects the deployment of an effective completion mechanism and as such, this endeavour should be carried out conscientiously.","PeriodicalId":399294,"journal":{"name":"Day 2 Tue, August 02, 2022","volume":"30 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130757111","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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