E. Ayodele, David Ekuma, I. Okafor, Innocent E Nweze
Drilling fluid are complex fluids consisting of several additives. These additives are added to enhance and control the rheological properties (such as viscosity, gel strength and yield point) of the mud. These properties are controlled for effective drilling of a well. This research work is focused on determining the rheological behavior of drilling mud using industry-based polymer and Irvingia Gabonensis (ogbono) as viscosifiers. Water based muds were formulated from the aforementioned locally sourced viscosifier and that of the conventional used viscosifier (Carboxylmetyl cellulose, CMC). Laboratory tests were carried out on the different muds formulated and their rheological properties (such as yield stress, shear stress, plastic viscosity and shear rate) are evaluated. The concentration of the viscosifiers were varied. The expected outcome of the research work aims at lowering the total drilling cost by reducing the importation of foreign polymer which promotes the development of local content in the oil and gas industry. The research compares the rheology of mud samples and the effect of varying the concentration (2g, 4g, 6g, 8g, and 10g) of both CMC and Ogbono and determining the changes in their rheological properties. The total volume of each mud sample is equivalent to 350ml which represent one barrel (42gal) in the lab. From the result, at concentration of 2g, the ogbono mud has a better rheology than the CMC mud, but at a concentration above 2g, CMC mud shows a better rheology than ogbono mud, that is, as the concentration of CMC is increased, the rheological properties of the mud increased while as the concentration of ogbono is increased the rheological properties decreased. The viscosity of the drilling fluid produced from the ogbono were lower than that of CMC, it could be used together with another local product such as cassava starch, offor or to further improve the rheology and then be a substitute to the conventional viscosifiers.
{"title":"Comparative Analysis of the Rheological Behaviour of Irvingia Gabonensis Ogbono and Foreign Polymer for Bentonite Formulated Mud.","authors":"E. Ayodele, David Ekuma, I. Okafor, Innocent E Nweze","doi":"10.2118/207112-ms","DOIUrl":"https://doi.org/10.2118/207112-ms","url":null,"abstract":"\u0000 Drilling fluid are complex fluids consisting of several additives. These additives are added to enhance and control the rheological properties (such as viscosity, gel strength and yield point) of the mud. These properties are controlled for effective drilling of a well. This research work is focused on determining the rheological behavior of drilling mud using industry-based polymer and Irvingia Gabonensis (ogbono) as viscosifiers. Water based muds were formulated from the aforementioned locally sourced viscosifier and that of the conventional used viscosifier (Carboxylmetyl cellulose, CMC). Laboratory tests were carried out on the different muds formulated and their rheological properties (such as yield stress, shear stress, plastic viscosity and shear rate) are evaluated. The concentration of the viscosifiers were varied. The expected outcome of the research work aims at lowering the total drilling cost by reducing the importation of foreign polymer which promotes the development of local content in the oil and gas industry. The research compares the rheology of mud samples and the effect of varying the concentration (2g, 4g, 6g, 8g, and 10g) of both CMC and Ogbono and determining the changes in their rheological properties. The total volume of each mud sample is equivalent to 350ml which represent one barrel (42gal) in the lab. From the result, at concentration of 2g, the ogbono mud has a better rheology than the CMC mud, but at a concentration above 2g, CMC mud shows a better rheology than ogbono mud, that is, as the concentration of CMC is increased, the rheological properties of the mud increased while as the concentration of ogbono is increased the rheological properties decreased. The viscosity of the drilling fluid produced from the ogbono were lower than that of CMC, it could be used together with another local product such as cassava starch, offor or to further improve the rheology and then be a substitute to the conventional viscosifiers.","PeriodicalId":10899,"journal":{"name":"Day 2 Tue, August 03, 2021","volume":"41 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76248629","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}
Assurance of reliable public health and safety of/in work environments patently depends on the Emotional Intelligence (EI) of workers. EI, which is the ability to understand and regulate emotions of one-self and others, is one of the uncommonly utilized strategies to optimizing deliverability in workplaces. Work pressure can never be overemphasized, as when not managed effectively, can retard compliance to industry set rules, integrity, and values, as well as distort deliverability of workers. The oil and gas sector were not left out in the impact of the COVID-19 pandemic which did not only affect the economy of the global oil market, but also, jeopardized the health and safety of its workers and the environment at large. This paper highlights Emotional Intelligence (EI) as a method to curb the negative effects which the pandemic has caused. It further positions Affability as a must-have skill for oil and gas workers for the purpose of assuring health and safety in work environments. Conceptual and critical thinking processes were utilized to introduce and prioritize Affability as an aspect of EI to proffering solutions to threats regarding safe and workable environment in the industry. Using SPSS, a comprehensive analytical result was generated for 102 oil and gas workers in Nigeria, who took an Emotional Intelligence test compiled by Global Leadership Foundation. A mean of 45.35% was calculated with 57% of 102 scoring below %50. A critical observation indicates that, EI among oil and gas workers was unreliable. This is due to unawareness to effectiveness of developing affable skills to combat safety and health threats in work environments. In an informative way, this paper introduces Affability as a core aspect of Emotional Intelligence and its effectual contribution to promoting a healthy and safe oil and gas work environment.
{"title":"Emotional Intelligence: A Modern Approach to Health and Safety in the Oil and Gas Industry, Effects of Covid-19 Pandemic in Work Environments, and Solutions to Enhance Work Deliverability - A Case Study of Nigeria","authors":"Justice Osuala, Matilda Obuh","doi":"10.2118/208242-ms","DOIUrl":"https://doi.org/10.2118/208242-ms","url":null,"abstract":"\u0000 Assurance of reliable public health and safety of/in work environments patently depends on the Emotional Intelligence (EI) of workers. EI, which is the ability to understand and regulate emotions of one-self and others, is one of the uncommonly utilized strategies to optimizing deliverability in workplaces. Work pressure can never be overemphasized, as when not managed effectively, can retard compliance to industry set rules, integrity, and values, as well as distort deliverability of workers. The oil and gas sector were not left out in the impact of the COVID-19 pandemic which did not only affect the economy of the global oil market, but also, jeopardized the health and safety of its workers and the environment at large. This paper highlights Emotional Intelligence (EI) as a method to curb the negative effects which the pandemic has caused. It further positions Affability as a must-have skill for oil and gas workers for the purpose of assuring health and safety in work environments. Conceptual and critical thinking processes were utilized to introduce and prioritize Affability as an aspect of EI to proffering solutions to threats regarding safe and workable environment in the industry. Using SPSS, a comprehensive analytical result was generated for 102 oil and gas workers in Nigeria, who took an Emotional Intelligence test compiled by Global Leadership Foundation. A mean of 45.35% was calculated with 57% of 102 scoring below %50. A critical observation indicates that, EI among oil and gas workers was unreliable. This is due to unawareness to effectiveness of developing affable skills to combat safety and health threats in work environments. In an informative way, this paper introduces Affability as a core aspect of Emotional Intelligence and its effectual contribution to promoting a healthy and safe oil and gas work environment.","PeriodicalId":10899,"journal":{"name":"Day 2 Tue, August 03, 2021","volume":"98 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77030465","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
The spread of infectious diseases such as COVID-19 in a typical oil and gas facility setting, the health of employees, their families and their communities, is of real concern to the industry. In this work, a suitable predictive, agent-based model is used to predict the spread of COVID-19 in different settings as well as to evaluate strategies to block the spread. The agent-based modelling work is based on the simulation platform, Complex Organization and Bifurcation Within Environmental Bounds, or COBWEB. COBWEB simulates how a system of autonomous agents adapts to variation and sudden changes in the resource base or other features of their environment. Previous COBWEB simulation results illustrate that the tool is useful for predicting the evolution of COVID-19 spread and the effectiveness of various preventive actions including self-isolation of symptomatic people, social/physical distancing, effective PPE use, and ‘shielding’ (physical isolation) of the high-risk population. We adapted model parameters to better represent uncertainty about what might be expected in such a setting, in particular by shifting the distribution of risk severity towards ineffective PPE use, self-isolation and poor social distancing, which expectedly shows upward trend of the spread of the COVID-19. Ultimately, governments and industry can apply the predicted trends, as well as apply the model to specific settings, to make more informed decisions on the additional measures and preventative strategies to curb the spread of COVID-19.
{"title":"Modelling the Spread of Covid-19 in a Typical Oil and Gas Facility Setting","authors":"Emeka Okafor, B. Bass","doi":"10.2118/207177-ms","DOIUrl":"https://doi.org/10.2118/207177-ms","url":null,"abstract":"\u0000 The spread of infectious diseases such as COVID-19 in a typical oil and gas facility setting, the health of employees, their families and their communities, is of real concern to the industry. In this work, a suitable predictive, agent-based model is used to predict the spread of COVID-19 in different settings as well as to evaluate strategies to block the spread. The agent-based modelling work is based on the simulation platform, Complex Organization and Bifurcation Within Environmental Bounds, or COBWEB. COBWEB simulates how a system of autonomous agents adapts to variation and sudden changes in the resource base or other features of their environment. Previous COBWEB simulation results illustrate that the tool is useful for predicting the evolution of COVID-19 spread and the effectiveness of various preventive actions including self-isolation of symptomatic people, social/physical distancing, effective PPE use, and ‘shielding’ (physical isolation) of the high-risk population. We adapted model parameters to better represent uncertainty about what might be expected in such a setting, in particular by shifting the distribution of risk severity towards ineffective PPE use, self-isolation and poor social distancing, which expectedly shows upward trend of the spread of the COVID-19. Ultimately, governments and industry can apply the predicted trends, as well as apply the model to specific settings, to make more informed decisions on the additional measures and preventative strategies to curb the spread of COVID-19.","PeriodicalId":10899,"journal":{"name":"Day 2 Tue, August 03, 2021","volume":"43 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79701902","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}
S. Eyitayo, K. Lawal, I. Abdullahi, S. Matemilola, John Akadang, Victor Anyanwu, Bernard Ainoje, Tunde Alabi, S. Owolabi
Production-screening test (PST) is performed on a reservoir drill-in fluid (RDIF) prior to running any component of the lower completion assembly that is vulnerable to plugging. This is applicable in open-hole completions in which wire-wrapped production screens are deployed. The key objective of a PST is to reduce the risk of plugging key completion components, such as production screens, during subsequent flow back. Hence, a PST increases the chance of preserving well productivity (or injectivity), ultimate recovery and project economics. However, conducting and achieving PST-quality RDIF in offshore fields can be cumbersome, time-consuming, and expensive, yet the quality is not guaranteed. This paper presents the formulation, implementation, and results of a simple strategy to reduce the turnaround time and costs of achieving PST-quality RDIF for applications in offshore fields. Employing a combination of on-the-job assessment, empirical data and expert opinions, the strengths and weaknesses of onsite versus offsite (onshore) options of preparing PST-quality RDIF for offshore operations are evaluated. As a case-study, empirical data from the execution of both onsite and offsite options for an example field are employed for the evaluation. Results of simple cost-time-benefit analysis underscore the robustness and competitiveness of preparing the PST-quality RDIF offsite and transporting same for subsequent test validation and application on the rig. The results of these empirical examples show that the offsite option yields about 75% cost-saving relative to its onsite counterpart. In addition to cost saving, other incremental benefits of the former include (i) significant reduction in rig time and personnel; (ii) improved RDIF quality; and (iii) higher chances of preserving well performance and economics. To increase the success rate, residual risks of the preferred offsite option are outlined, and relevant mitigations provided.
{"title":"Optimization of the Turnaround Time and Quality of Production-Screening Tests in Offshore Fields – Some Case Studies","authors":"S. Eyitayo, K. Lawal, I. Abdullahi, S. Matemilola, John Akadang, Victor Anyanwu, Bernard Ainoje, Tunde Alabi, S. Owolabi","doi":"10.2118/207105-ms","DOIUrl":"https://doi.org/10.2118/207105-ms","url":null,"abstract":"\u0000 Production-screening test (PST) is performed on a reservoir drill-in fluid (RDIF) prior to running any component of the lower completion assembly that is vulnerable to plugging. This is applicable in open-hole completions in which wire-wrapped production screens are deployed. The key objective of a PST is to reduce the risk of plugging key completion components, such as production screens, during subsequent flow back. Hence, a PST increases the chance of preserving well productivity (or injectivity), ultimate recovery and project economics. However, conducting and achieving PST-quality RDIF in offshore fields can be cumbersome, time-consuming, and expensive, yet the quality is not guaranteed.\u0000 This paper presents the formulation, implementation, and results of a simple strategy to reduce the turnaround time and costs of achieving PST-quality RDIF for applications in offshore fields. Employing a combination of on-the-job assessment, empirical data and expert opinions, the strengths and weaknesses of onsite versus offsite (onshore) options of preparing PST-quality RDIF for offshore operations are evaluated.\u0000 As a case-study, empirical data from the execution of both onsite and offsite options for an example field are employed for the evaluation. Results of simple cost-time-benefit analysis underscore the robustness and competitiveness of preparing the PST-quality RDIF offsite and transporting same for subsequent test validation and application on the rig.\u0000 The results of these empirical examples show that the offsite option yields about 75% cost-saving relative to its onsite counterpart. In addition to cost saving, other incremental benefits of the former include (i) significant reduction in rig time and personnel; (ii) improved RDIF quality; and (iii) higher chances of preserving well performance and economics. To increase the success rate, residual risks of the preferred offsite option are outlined, and relevant mitigations provided.","PeriodicalId":10899,"journal":{"name":"Day 2 Tue, August 03, 2021","volume":"28 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89651001","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}
As hydrocarbon formation continues, owing to its natural sourcing, technologies have continually emerged on how these hydrocarbons can be effectively produced at a commercial benchmark. Asides its natural drive system, the enhanced oil recovery methods have been one key approach that has been effected towards increasing hydrocarbon's production rate, from its reservoirs. The natural reservoir energy has allowed for about 10% production of original oil in place. And, extending a field's productive life by employing the secondary recovery has further improved production to 20 to 40%, with EOR amounting to about 30 to 60% production. This however, would tell of the impending need towards further developments on increasing upon this production rate. Hence, the approach on using a pneumatic operated assembly with considerations made on onshore wells. This paper seeks to depict a focal on "Pneumatic IOR (Improved Oil Recovery)" as a method to be effected for onshore wells towards improving its productivity. The pneumatic system uses compressed air, contained in a cylinder - through specialized tubing, alongside pressure control systems, that helps regulate the flow and amount of the compressed air; to propel a metallic bar that will act on the reservoir surface. A force of impact, which will induce vibrations inwards, is generated. The mechanical motion of the metal bars for which this compressed air acts upon will provide the travel force, which when it acts on the reservoir surface of interest, will induce geologic stresses. This stresses and vibrations are important constituents in increasing pressure, downhole. Thereby, enabling fluid flow upwards through the wellbore to the surface. And, this will proffer the necessary physics, needed for pressure development downhole, which will be of importance in improving Oil Recovery.
{"title":"Effecting a Pneumatic Operated Assembly, for an Improved Oil Recovery IOR, in Onshore Wells","authors":"Abednego Ishaya, Wakili","doi":"10.2118/207199-ms","DOIUrl":"https://doi.org/10.2118/207199-ms","url":null,"abstract":"\u0000 As hydrocarbon formation continues, owing to its natural sourcing, technologies have continually emerged on how these hydrocarbons can be effectively produced at a commercial benchmark. Asides its natural drive system, the enhanced oil recovery methods have been one key approach that has been effected towards increasing hydrocarbon's production rate, from its reservoirs. The natural reservoir energy has allowed for about 10% production of original oil in place. And, extending a field's productive life by employing the secondary recovery has further improved production to 20 to 40%, with EOR amounting to about 30 to 60% production.\u0000 This however, would tell of the impending need towards further developments on increasing upon this production rate. Hence, the approach on using a pneumatic operated assembly with considerations made on onshore wells. This paper seeks to depict a focal on \"Pneumatic IOR (Improved Oil Recovery)\" as a method to be effected for onshore wells towards improving its productivity.\u0000 The pneumatic system uses compressed air, contained in a cylinder - through specialized tubing, alongside pressure control systems, that helps regulate the flow and amount of the compressed air; to propel a metallic bar that will act on the reservoir surface. A force of impact, which will induce vibrations inwards, is generated. The mechanical motion of the metal bars for which this compressed air acts upon will provide the travel force, which when it acts on the reservoir surface of interest, will induce geologic stresses. This stresses and vibrations are important constituents in increasing pressure, downhole. Thereby, enabling fluid flow upwards through the wellbore to the surface.\u0000 And, this will proffer the necessary physics, needed for pressure development downhole, which will be of importance in improving Oil Recovery.","PeriodicalId":10899,"journal":{"name":"Day 2 Tue, August 03, 2021","volume":"24 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91000055","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 recent years, several research types have been carried out to produce environmentally-benign drilling fluid additives using locally sourced substances. Still, the formulation of a more effective and cheaper viscosifier for a better hole cleaning ability that lowers risk in lost circulation zones, especially at higher temperatures, remains a critical research subject. This study examines the use of Sweet Potato Peels Extract (PPE), a more readily available by-product, as a drilling fluid additive. A 23 factorial experiment that considers temperature, PPE and Xanthan Gum (X.G.) as factor variables and viscosity as a response variable was conducted for field optimisation. In this research, the PPE and other commercial polymers were measured at different concentrations and combined in a specified ratio of 1:1 by mass to verify the levels of interaction between the additives on the mud weight, yield point (Y.P.), and plastic viscosity (P.V.) of the formulated drilling mud. The additives’ effects were then recorded using a mud balance, a viscometer, and a heater for temperature variance. The results were then compared with the control mud to ascertain the additives’ effectiveness. Experimental results revealed that the PPE and X.G. increased the Y.P. and P.V. at 104 °F and 176 °F, respectively. On adding 6 g of X.G. to the control mud (8.97 ppg), at 104 °F and 176 °F, the Y.P. increased by 88% and 11%, respectively, and the 3 g PPE + 3 g X.G. gave a better inference at 104 °F and 176 °F with a 92% and 38% increase respectively. This increase is a result of higher potassium content in the PPE from chemical laboratory analysis. Apart from the optimum ratio by mass of 1:1 above, the combination effects or results are shown using the factorial design experiment. The factor variables were modelled into a mathematical equation that indicates PPE additive as the most significant parameter on the yield point. The second component of viscosity, plastic viscosity (P.V.), followed a similar trend. Furthermore, PPE and X.G.'s effect on plastic viscosity at 176 °F decreased slightly with an increase in the control mud's salinity. This novel combination offers a more cost-effective and better-performing viscosifier than the conventional X.G. from the above results. The model helps predict downhole conditions better as it shows the interactive effects of the various additives and can help inform decisions at the surface. A better hole cleaning ability, lower risk in lost circulation zones, and reduced Non-Productive Time would be the benefits of using this formulation.
近年来，已经开展了几种类型的研究，以使用本地物质生产环保型钻井液添加剂。尽管如此，寻找一种更有效、更便宜的增粘剂，以提高井眼清洁能力，降低井眼漏失风险，特别是在高温下，仍然是一个重要的研究课题。本研究考察了甘薯皮提取物(PPE)作为钻井液添加剂的使用，这是一种更容易获得的副产品。以温度、PPE和黄原胶(X.G.)为因素变量，粘度为响应变量，进行了23因子实验，进行了现场优化。在这项研究中，PPE和其他商业聚合物在不同浓度下进行了测量，并以1:1的特定质量比组合，以验证添加剂对泥浆重量、屈服点(Y.P.)和塑性粘度(P.V.)的相互作用水平。然后使用泥浆天平、粘度计和温度变化加热器记录添加剂的影响。然后将结果与对照泥浆进行比较，以确定添加剂的有效性。实验结果表明，PPE和X.G.分别在104°F和176°F时提高了Y.P.和P.V.。在104°F和176°F的温度下，在对照泥浆(8.97 ppg)中加入6 g的X.G.， Y.P.分别提高了88%和11%，而在104°F和176°F的温度下，3g PPE + 3g X.G.的推断效果更好，分别提高了92%和38%。这一增加是化学实验室分析得出的PPE中钾含量较高的结果。除上述最佳质量比为1:1外，采用析因设计试验显示了组合效果或结果。这些因素变量被建模成一个数学方程，表明PPE添加剂是对屈服点最重要的参数。粘度的第二个组成部分，塑性粘度(P.V.)，也遵循类似的趋势。此外，PPE和X.G.在176°F时，随着对照泥浆矿化度的增加，对塑性粘度的影响略有下降。从上述结果来看，这种新颖的组合提供了一种比传统的X.G.更具成本效益和更好性能的增粘剂。该模型可以更好地预测井下状况，因为它显示了各种添加剂的相互作用，并有助于为地面决策提供信息。使用该配方的好处是具有更好的井眼清洁能力、更低的漏失风险和更短的非生产时间。
{"title":"Factorial Design Validation of an Environmentally Benign Water-Based Drilling Fluid from Sweet Potato Peels at Elevated Temperatures","authors":"Ifeanyichukwu Ebuzeme, O. Olatunji, B. Olufemi","doi":"10.2118/207097-ms","DOIUrl":"https://doi.org/10.2118/207097-ms","url":null,"abstract":"\u0000 In recent years, several research types have been carried out to produce environmentally-benign drilling fluid additives using locally sourced substances. Still, the formulation of a more effective and cheaper viscosifier for a better hole cleaning ability that lowers risk in lost circulation zones, especially at higher temperatures, remains a critical research subject. This study examines the use of Sweet Potato Peels Extract (PPE), a more readily available by-product, as a drilling fluid additive. A 23 factorial experiment that considers temperature, PPE and Xanthan Gum (X.G.) as factor variables and viscosity as a response variable was conducted for field optimisation.\u0000 In this research, the PPE and other commercial polymers were measured at different concentrations and combined in a specified ratio of 1:1 by mass to verify the levels of interaction between the additives on the mud weight, yield point (Y.P.), and plastic viscosity (P.V.) of the formulated drilling mud. The additives’ effects were then recorded using a mud balance, a viscometer, and a heater for temperature variance. The results were then compared with the control mud to ascertain the additives’ effectiveness.\u0000 Experimental results revealed that the PPE and X.G. increased the Y.P. and P.V. at 104 °F and 176 °F, respectively. On adding 6 g of X.G. to the control mud (8.97 ppg), at 104 °F and 176 °F, the Y.P. increased by 88% and 11%, respectively, and the 3 g PPE + 3 g X.G. gave a better inference at 104 °F and 176 °F with a 92% and 38% increase respectively. This increase is a result of higher potassium content in the PPE from chemical laboratory analysis. Apart from the optimum ratio by mass of 1:1 above, the combination effects or results are shown using the factorial design experiment. The factor variables were modelled into a mathematical equation that indicates PPE additive as the most significant parameter on the yield point. The second component of viscosity, plastic viscosity (P.V.), followed a similar trend. Furthermore, PPE and X.G.'s effect on plastic viscosity at 176 °F decreased slightly with an increase in the control mud's salinity.\u0000 This novel combination offers a more cost-effective and better-performing viscosifier than the conventional X.G. from the above results. The model helps predict downhole conditions better as it shows the interactive effects of the various additives and can help inform decisions at the surface. A better hole cleaning ability, lower risk in lost circulation zones, and reduced Non-Productive Time would be the benefits of using this formulation.","PeriodicalId":10899,"journal":{"name":"Day 2 Tue, August 03, 2021","volume":"4 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84221038","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}
E. Ayodele, Ndubuisi Chukuigwe, Oshogwe Akpogomeh, Ibrahim Bilal
Petroleum product needs to be stored and transported from various sources before they get to the final consumers, there by requiring storage tanks. Calibration of storage tank by dry and wet strapping process have evolved over the years with state-of-the-art facilities. The calibration charts are used to determine and know the volume of fluid in a tank given the height of the petroleum products stored in the tank. Calculating volume of a tank with the integration method has a lot of sources of error thereby affecting the result of the volume calculated and causing losses in revenue due to inaccurate calibrated tanks. With the losses in revenue due to wrong computations or computational errors, a fast, dynamic and cost-effective solutions become imperative to solve these computation problems. The tank charts having been delivered for daily usage and fiscalization process after the tank strapping process, calculation errors need to be minimized in order to report accurately petroleum products in stocks, which is a function of temperature, density and volume correction factor. This paper aims to solve the problem by semi automating the process of calculating total volume of product in stock with error free results. Approach in this paper was used and test run for a storage facility X. This paper shows how calculations from calibrated tanks can be done with a virtual method using excel spreadsheet and converted into a software for effective use and making percentage error almost zero. The results obtained from this method of computation were error free and devoid of human errors.
{"title":"Digital Transformation of Storage Tank Chart For PMS and AGO","authors":"E. Ayodele, Ndubuisi Chukuigwe, Oshogwe Akpogomeh, Ibrahim Bilal","doi":"10.2118/207166-ms","DOIUrl":"https://doi.org/10.2118/207166-ms","url":null,"abstract":"\u0000 Petroleum product needs to be stored and transported from various sources before they get to the final consumers, there by requiring storage tanks. Calibration of storage tank by dry and wet strapping process have evolved over the years with state-of-the-art facilities. The calibration charts are used to determine and know the volume of fluid in a tank given the height of the petroleum products stored in the tank. Calculating volume of a tank with the integration method has a lot of sources of error thereby affecting the result of the volume calculated and causing losses in revenue due to inaccurate calibrated tanks. With the losses in revenue due to wrong computations or computational errors, a fast, dynamic and cost-effective solutions become imperative to solve these computation problems. The tank charts having been delivered for daily usage and fiscalization process after the tank strapping process, calculation errors need to be minimized in order to report accurately petroleum products in stocks, which is a function of temperature, density and volume correction factor. This paper aims to solve the problem by semi automating the process of calculating total volume of product in stock with error free results. Approach in this paper was used and test run for a storage facility X. This paper shows how calculations from calibrated tanks can be done with a virtual method using excel spreadsheet and converted into a software for effective use and making percentage error almost zero. The results obtained from this method of computation were error free and devoid of human errors.","PeriodicalId":10899,"journal":{"name":"Day 2 Tue, August 03, 2021","volume":"17 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84422923","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}
Drilling detergents are among the chemical compounds that are increasingly being used in many varieties of drilling fluids. They are aqueous blend of surface-active agents that reduces the surface tension of water-based drilling fluids, reduces the sticking tendency of water-sensitive shale cuttings and aid cuttings removal; leading to cleaner hole, faster penetration rates and lower drilling pressure. Due to the increase in environmental issues associated with the disposal of drilling detergent presently used, drilling companies are exploring options of using environmentally friendly, degradable and renewable drilling detergents. In this study, biodetergents were produced from non-edible seed oils (Ricinus communis oil and Azadirachta Indica oil). The biodetergents and a commercial drilling detergent used in the Niger Delta field were analysed for a number of standard properties required for good drilling detergents. Drilling muds formulated with these detergents were also analysed for a number of standard mud properties. Physicochemical properties analyses showed that biodetergents met the required specification of good drilling detergents. The physicochemical properties of the biodetergents were also comparable to that of commercial drilling detergent. BOD values obtained showed that the biodetergents could easily be broken or biodegraded than the commercial drilling detergent. Toxicity test on Penaeus Monodon showed that biodetergents are more environmentally friendly than the commercial drilling detergent. Drilling mud properties analyses further showed that synthesized biodetergents can be used as an alternative to conventional drilling detergent.
{"title":"Production and Performance Evaluation of Biodetergents as an Alternative to Conventional Drilling Detergent","authors":"A. A. Azuokwu, Y. Yerima, R. Azike","doi":"10.2118/207167-ms","DOIUrl":"https://doi.org/10.2118/207167-ms","url":null,"abstract":"\u0000 Drilling detergents are among the chemical compounds that are increasingly being used in many varieties of drilling fluids. They are aqueous blend of surface-active agents that reduces the surface tension of water-based drilling fluids, reduces the sticking tendency of water-sensitive shale cuttings and aid cuttings removal; leading to cleaner hole, faster penetration rates and lower drilling pressure.\u0000 Due to the increase in environmental issues associated with the disposal of drilling detergent presently used, drilling companies are exploring options of using environmentally friendly, degradable and renewable drilling detergents.\u0000 In this study, biodetergents were produced from non-edible seed oils (Ricinus communis oil and Azadirachta Indica oil). The biodetergents and a commercial drilling detergent used in the Niger Delta field were analysed for a number of standard properties required for good drilling detergents. Drilling muds formulated with these detergents were also analysed for a number of standard mud properties.\u0000 Physicochemical properties analyses showed that biodetergents met the required specification of good drilling detergents. The physicochemical properties of the biodetergents were also comparable to that of commercial drilling detergent. BOD values obtained showed that the biodetergents could easily be broken or biodegraded than the commercial drilling detergent. Toxicity test on Penaeus Monodon showed that biodetergents are more environmentally friendly than the commercial drilling detergent. Drilling mud properties analyses further showed that synthesized biodetergents can be used as an alternative to conventional drilling detergent.","PeriodicalId":10899,"journal":{"name":"Day 2 Tue, August 03, 2021","volume":"25 11","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"72551544","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}
Condensate reservoirs are mostly pressure sensitive and keeping the pressure above the dew point pressure in the reservoir is critical to avoid condensate banking in the reservoir. If it occurs, production is highly inhibited and the well may ultimately quit on production under liquid loading. Fluid ratios are important in the management of condensate wells and most critical is the Gas Liquid Ratio (GLR). There is a certain GLR that below it, there will be a liquid loading in the wellbore that could quit the well. Each fluid rate goes with a GLR and the point where there is a reversal of the GLR or CGR trends may present a case of loading scenario and that is taken as the determination reference point. When a condensate well shows an improvement of water cut as the choke bean size is reduced does not necessarily signify a healthy situation and neither a one-point higher water cut with increase in choke bean size mean a water coning situation. When a liquid loading well is beaned up, there is early signs of water coning in the production data but this is just a wellbore production and the BS&W improves as the production rate is further increased. Further investigation is necessary to separate the challenge of water conning from the challenge of too low Gas rate which causes the loading of the liquids in the wellbore. That is the operating envelop to manage condensate well rates: rates too low with a possibility of a liquid loading and rates too high that depicts a case of water conning when water is close to the perforation. This band must be completely exploited to turn the production curve in the positive. This paper provides a strategy to recover a condensate well production with a challenge of liquid loading using a case study. The degree of the severity of the liquid loading can be represented using a power law model with the gradient being the level of severity of the loading. The production improvement is greater than nβ percent where n is the quadratic model number 2 and β is the product of the graphical and Lagrangian-Quadratic alpha parameters. The optimum rate can be determined using the Lagrange Multiplier optimization method to effectively extend the production life of the well.
{"title":"Determination of Optimum Rate in a Condensate Well with a Case of a Wellbore Liquid Loading","authors":"M. P. Ekeregbe","doi":"10.2118/207119-ms","DOIUrl":"https://doi.org/10.2118/207119-ms","url":null,"abstract":"\u0000 Condensate reservoirs are mostly pressure sensitive and keeping the pressure above the dew point pressure in the reservoir is critical to avoid condensate banking in the reservoir. If it occurs, production is highly inhibited and the well may ultimately quit on production under liquid loading.\u0000 Fluid ratios are important in the management of condensate wells and most critical is the Gas Liquid Ratio (GLR). There is a certain GLR that below it, there will be a liquid loading in the wellbore that could quit the well. Each fluid rate goes with a GLR and the point where there is a reversal of the GLR or CGR trends may present a case of loading scenario and that is taken as the determination reference point. When a condensate well shows an improvement of water cut as the choke bean size is reduced does not necessarily signify a healthy situation and neither a one-point higher water cut with increase in choke bean size mean a water coning situation. When a liquid loading well is beaned up, there is early signs of water coning in the production data but this is just a wellbore production and the BS&W improves as the production rate is further increased.\u0000 Further investigation is necessary to separate the challenge of water conning from the challenge of too low Gas rate which causes the loading of the liquids in the wellbore. That is the operating envelop to manage condensate well rates: rates too low with a possibility of a liquid loading and rates too high that depicts a case of water conning when water is close to the perforation. This band must be completely exploited to turn the production curve in the positive.\u0000 This paper provides a strategy to recover a condensate well production with a challenge of liquid loading using a case study. The degree of the severity of the liquid loading can be represented using a power law model with the gradient being the level of severity of the loading. The production improvement is greater than nβ percent where n is the quadratic model number 2 and β is the product of the graphical and Lagrangian-Quadratic alpha parameters. The optimum rate can be determined using the Lagrange Multiplier optimization method to effectively extend the production life of the well.","PeriodicalId":10899,"journal":{"name":"Day 2 Tue, August 03, 2021","volume":"148 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77848965","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
The prediction of slug frequency for two-phase slug flow during multiphase transportation of oil reservoir productions is crucial in the design of slug controllers for petroleum processing installations. Mechanistic based slug prediction models have not had much successful application due to the difficulty in modelling the non-linear interface motion during slug development. The mechanism of slugging in offshore flowline-riser is complicated and requires rigorous experimental sampling and testing. This process can be time-consuming and costly. In this study, a new correlation is developed for the prediction of severe slugging frequency. The new model is developed based on the results of scaled experimental design. Dimensional analysis approach using the Buckingham pi-theorem is used in developing the two-phase correlation. The model development involves non-dimensional empirical correlations in terms of relevant dimensionless groups, which are obtained based on the design of the experiment. A broad range of experimental data from 10 varied choke opening size was used. The new correlation predicts 92.3% of the measurements within ±8% absolute error and the mean absolute deviation of the correlation is about 6.13%. The newly developed correlation can be applied for flow rates between 0.1 kg/s and 0.6 kg/s and choke openings between 10-98%.
{"title":"Slug Frequency Prediction Model for Fluid Flow in Flowline Bends","authors":"L. Igbokwe, Michael Edwin","doi":"10.2118/208233-ms","DOIUrl":"https://doi.org/10.2118/208233-ms","url":null,"abstract":"\u0000 The prediction of slug frequency for two-phase slug flow during multiphase transportation of oil reservoir productions is crucial in the design of slug controllers for petroleum processing installations. Mechanistic based slug prediction models have not had much successful application due to the difficulty in modelling the non-linear interface motion during slug development. The mechanism of slugging in offshore flowline-riser is complicated and requires rigorous experimental sampling and testing. This process can be time-consuming and costly. In this study, a new correlation is developed for the prediction of severe slugging frequency. The new model is developed based on the results of scaled experimental design. Dimensional analysis approach using the Buckingham pi-theorem is used in developing the two-phase correlation. The model development involves non-dimensional empirical correlations in terms of relevant dimensionless groups, which are obtained based on the design of the experiment. A broad range of experimental data from 10 varied choke opening size was used. The new correlation predicts 92.3% of the measurements within ±8% absolute error and the mean absolute deviation of the correlation is about 6.13%. The newly developed correlation can be applied for flow rates between 0.1 kg/s and 0.6 kg/s and choke openings between 10-98%.","PeriodicalId":10899,"journal":{"name":"Day 2 Tue, August 03, 2021","volume":"24 4 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91055047","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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