K. Hannah, Maku Gbenga, Ike Micheal, Olagunju Khalid, Ojo Olaniyi, O. James
Interruption in drilling operation occurs when drilling bit penetrates permeable gas sand with formation pressure greater than the pressure exerted by the drilling fluid in use. Consequently, due to pressure imbalance, there is an extraneous influx of gas into the wellbore, which would bring the drilling progress to a stop as it is necessary to restore pressure/fluid equilibrium throughout the system to contain the kick. This study presents a case study where a gas kick was unconventionally managed. While drilling 8 ½" hole at 11,682 ft, a mud gush shooting up through the rotary table to the stabbing board was observed. In attempt to shut-in the well, an accidental shear of the pipe at the surface occurred with the top of fish at 51 ft and with no means of circulating out the influx from the bottom of the well. Due to the well control issue, the cut pipe could not be reached to mill the top of the fish, prior to engaging same. The well was therefore put under control employing Lubricate and Bleed (LB) approach, which is a well control procedure applied in peculiar cases or situation, this is a method or procedure of removing gas in hole when there is no possible way of circulation. The sheared pipe located at about 52 ft below rotary, the Top Of fish was dressed from 51ft to 52ft and the string was eventually severed at 11460 ft, the rest 222 ft of fish was recovered using Overshot, Burn Shoe and Wash-Over assembly. With the effective application of the LB approach, the well was restored, and fish recovered within a relatively short period of time such that values weren't eroded. The approach employed in this study could be applied in a case of accidental shearing of the pipe such that the whole drilling progress is not brought to a total stop. The consequence of not exploring this approach is an additional cost of drilling a sidetrack well or totally abandoning the well. This paper can be used as a training tool to sharpen and build confidence in tackling well control using volumetric bleeding method. As this method is rare, and not simulated for during most well control certification exercises, it will be beneficial to a practicing engineer and can reduce some of the errors that could occur in a rare case of sheared pipe / well control.
{"title":"Unconventional Approach to Managing Kick During Gas Well Drilling","authors":"K. Hannah, Maku Gbenga, Ike Micheal, Olagunju Khalid, Ojo Olaniyi, O. James","doi":"10.2118/198845-MS","DOIUrl":"https://doi.org/10.2118/198845-MS","url":null,"abstract":"\u0000 Interruption in drilling operation occurs when drilling bit penetrates permeable gas sand with formation pressure greater than the pressure exerted by the drilling fluid in use. Consequently, due to pressure imbalance, there is an extraneous influx of gas into the wellbore, which would bring the drilling progress to a stop as it is necessary to restore pressure/fluid equilibrium throughout the system to contain the kick.\u0000 This study presents a case study where a gas kick was unconventionally managed.\u0000 While drilling 8 ½\" hole at 11,682 ft, a mud gush shooting up through the rotary table to the stabbing board was observed. In attempt to shut-in the well, an accidental shear of the pipe at the surface occurred with the top of fish at 51 ft and with no means of circulating out the influx from the bottom of the well. Due to the well control issue, the cut pipe could not be reached to mill the top of the fish, prior to engaging same. The well was therefore put under control employing Lubricate and Bleed (LB) approach, which is a well control procedure applied in peculiar cases or situation, this is a method or procedure of removing gas in hole when there is no possible way of circulation. The sheared pipe located at about 52 ft below rotary, the Top Of fish was dressed from 51ft to 52ft and the string was eventually severed at 11460 ft, the rest 222 ft of fish was recovered using Overshot, Burn Shoe and Wash-Over assembly.\u0000 With the effective application of the LB approach, the well was restored, and fish recovered within a relatively short period of time such that values weren't eroded.\u0000 The approach employed in this study could be applied in a case of accidental shearing of the pipe such that the whole drilling progress is not brought to a total stop. The consequence of not exploring this approach is an additional cost of drilling a sidetrack well or totally abandoning the well. This paper can be used as a training tool to sharpen and build confidence in tackling well control using volumetric bleeding method. As this method is rare, and not simulated for during most well control certification exercises, it will be beneficial to a practicing engineer and can reduce some of the errors that could occur in a rare case of sheared pipe / well control.","PeriodicalId":11110,"journal":{"name":"Day 2 Tue, August 06, 2019","volume":"60 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-08-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76203984","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 industry is in constant research with consistent efforts to ensure that the no/less incidents occur during the course of operations. Notable and popular slogans/rules have been adopted among engineering and oil & gas organizations over the years in the industry to intimate the need for safe activities to be performed among staff. Slogans like Goal Zero, Golden Rule dictum, "Safe…Yes we can", Life Saving Rules, "No Wahala…Take 5" and many others have been used in recent times to inculcate the culture of safety and situational awareness in the mind of the work force. Tools like check cards, stickers, safety IDs and banners are also quick reminders of the environment being operated on. However while all these tools are fairly efficient, the need for proper risk assessment cannot be over-emphasized at all times before a job to be done can be certified safe. Worksite Tools like toolbox talk, last minute risk assessment (LMRA), Job Hazard Analysis (JHA) and post job debrief are veritable towards achieving this goal. But while risk assessment before the job commences is important, of equivalent or even much importance is the one conducted during the job and this is called dynamic risk assessment. This paper presents an approach and exposition of the risk assessment plan in the operations level in the oil and gas industry. It also discussed on the methods to be deployed a successful risk assessment and buttress further on static and dynamic risk assessment as it concerns operations in a gas process plant. A new conceptual risk assessment model has been developed. A case study was treated from Atabala Plant which is a gas processing facility in the south southern Nigeria.
{"title":"Dynamic Risk Assessment – A MacGyverism to Worksite Incidents","authors":"E. Umeh","doi":"10.2118/198779-MS","DOIUrl":"https://doi.org/10.2118/198779-MS","url":null,"abstract":"\u0000 The industry is in constant research with consistent efforts to ensure that the no/less incidents occur during the course of operations. Notable and popular slogans/rules have been adopted among engineering and oil & gas organizations over the years in the industry to intimate the need for safe activities to be performed among staff. Slogans like Goal Zero, Golden Rule dictum, \"Safe…Yes we can\", Life Saving Rules, \"No Wahala…Take 5\" and many others have been used in recent times to inculcate the culture of safety and situational awareness in the mind of the work force. Tools like check cards, stickers, safety IDs and banners are also quick reminders of the environment being operated on.\u0000 However while all these tools are fairly efficient, the need for proper risk assessment cannot be over-emphasized at all times before a job to be done can be certified safe. Worksite Tools like toolbox talk, last minute risk assessment (LMRA), Job Hazard Analysis (JHA) and post job debrief are veritable towards achieving this goal. But while risk assessment before the job commences is important, of equivalent or even much importance is the one conducted during the job and this is called dynamic risk assessment.\u0000 This paper presents an approach and exposition of the risk assessment plan in the operations level in the oil and gas industry. It also discussed on the methods to be deployed a successful risk assessment and buttress further on static and dynamic risk assessment as it concerns operations in a gas process plant. A new conceptual risk assessment model has been developed. A case study was treated from Atabala Plant which is a gas processing facility in the south southern Nigeria.","PeriodicalId":11110,"journal":{"name":"Day 2 Tue, August 06, 2019","volume":"43 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-08-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85529045","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}
Heavy metals are present in crude oil produced worldwide in varying concentration as impurities. Such metals are also exposed to the environment when oil spill occur. In this study, we applied the duckweed, Lemna paucicostata as an ecological based treatment method for the phytoremediation of heavy metals present in crude oil polluted waters. Duckweed was applied in an artificial constructed wetland mesocosm contaminated with crude oil to simulate a spill site. Heavy metals were analyzed following established guidelines using AAS for a 60-day period. The results showed that heavy metals reported in this study were above permissible limit. Initial cadmium, chromium, lead and vanadium decreased by 4.36, 7.06, 17.95 and 2.47% after 15 days respectively and then decreased further by 11.21, 19.94 and 32.4% for Cd; 13.15, 16.9 and 13.76% for Cr; 20.51, 30.77 and 41.03% for Pb; and 4.12, 15.66 and 26.37% for V after 30, 45 and 60 days respectively. There was no significant difference between the mean values of the metals across the duration. The result of this study showed that duckweed moderately removed heavy metals from crude oil polluted waters. Extending the duration of the study could increase the potentials of the plant to remove a higher amount of metals from the contaminated media. This result could be translated to real life application as an ecological base tool for the sustainable remediation of metals in crude oil polluted environment.
{"title":"Ecological Remediation of Heavy Metals in Crude Oil Polluted Waters Using Duckweed","authors":"A. Ekperusi, F. Sikoki, E. Nwachukwu","doi":"10.2118/198773-MS","DOIUrl":"https://doi.org/10.2118/198773-MS","url":null,"abstract":"\u0000 Heavy metals are present in crude oil produced worldwide in varying concentration as impurities. Such metals are also exposed to the environment when oil spill occur. In this study, we applied the duckweed, Lemna paucicostata as an ecological based treatment method for the phytoremediation of heavy metals present in crude oil polluted waters. Duckweed was applied in an artificial constructed wetland mesocosm contaminated with crude oil to simulate a spill site. Heavy metals were analyzed following established guidelines using AAS for a 60-day period. The results showed that heavy metals reported in this study were above permissible limit. Initial cadmium, chromium, lead and vanadium decreased by 4.36, 7.06, 17.95 and 2.47% after 15 days respectively and then decreased further by 11.21, 19.94 and 32.4% for Cd; 13.15, 16.9 and 13.76% for Cr; 20.51, 30.77 and 41.03% for Pb; and 4.12, 15.66 and 26.37% for V after 30, 45 and 60 days respectively. There was no significant difference between the mean values of the metals across the duration. The result of this study showed that duckweed moderately removed heavy metals from crude oil polluted waters. Extending the duration of the study could increase the potentials of the plant to remove a higher amount of metals from the contaminated media. This result could be translated to real life application as an ecological base tool for the sustainable remediation of metals in crude oil polluted environment.","PeriodicalId":11110,"journal":{"name":"Day 2 Tue, August 06, 2019","volume":"13 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-08-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85864121","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}
Reservoir_B7 is one of the top reservoirs in Adobe field and was considered for further development in a multi-year drilling campaign. The initial opportunity identification and new drill forecasts for this reservoir were done using an old simulation model. Over the years, the challenge with this model had been the prediction water production from existing producers which necessitated the introduction of local permeability barriers in the model. However, to validate this opportunity and ensure reliability of production forecasts, a new simulation study was commissioned. A systematic approach was employed during the new study which involved continuous engagement between Earth Modeler and Simulation Engineer. This led to identification of a low-quality facies which had not been properly characterized. Recharacterization of these facies led to an improvement in history match with an overall good pressure and saturation matches on both well-by-well and reservoir levels. The latest history matched model was used to validate the proposed opportunity and indicated a sub-economic incremental recovery. This led to elimination of hitherto top opportunity from the drilling program and preventing a bad investment by the company.
{"title":"Resolution of a Perennial Water-Cut History Match Challenge Helps to Optimize Drilling Program","authors":"N. Yusuf, P. Andrew, Lynn Silpngarmlers","doi":"10.2118/198851-MS","DOIUrl":"https://doi.org/10.2118/198851-MS","url":null,"abstract":"\u0000 Reservoir_B7 is one of the top reservoirs in Adobe field and was considered for further development in a multi-year drilling campaign. The initial opportunity identification and new drill forecasts for this reservoir were done using an old simulation model. Over the years, the challenge with this model had been the prediction water production from existing producers which necessitated the introduction of local permeability barriers in the model. However, to validate this opportunity and ensure reliability of production forecasts, a new simulation study was commissioned.\u0000 A systematic approach was employed during the new study which involved continuous engagement between Earth Modeler and Simulation Engineer. This led to identification of a low-quality facies which had not been properly characterized. Recharacterization of these facies led to an improvement in history match with an overall good pressure and saturation matches on both well-by-well and reservoir levels. The latest history matched model was used to validate the proposed opportunity and indicated a sub-economic incremental recovery. This led to elimination of hitherto top opportunity from the drilling program and preventing a bad investment by the company.","PeriodicalId":11110,"journal":{"name":"Day 2 Tue, August 06, 2019","volume":"26 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-08-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82428771","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}
Virtue Urunwo Elechi, S. S. Ikiensikimama, J. Ajienka, O. Akaranta, M. Onyekonwu, O. Okon
This present study emphasizes the inhibition capacity of a local inhibitor, Plant Extract (PE) on structure I (sI) gas hydrate. The Plant Extract (PE) was screened using a mini flow loop made of 316 stainless steel of internal diameter of 0.5-inch encased in a 4-inch PVC pipe skid mounted on a metal frame work fitted with pressure and temperature gauges, mixer vessel, pumps and control switches. Pressure and Temperature readings were recorded for 120 minutes. Plots of Pressure and Temperature versus Time for 1, 2 and 3wt% of the local inhibitor alongside Pressure versus Time plot of PE and MEG were done as a way of comparison. Calculations for Inhibition Efficiency (IE) for local inhibitor PE and MEG was also done. 1wt% of the plant extract (PE) had a high inhibition efficiency of 84.21% while 2 and 3wt% had inhibition efficiency of 60.53% and 73.68% respectively. The overall inhibition efficiency of Plant Extract (PE) was higher than that of MEG for 1wt% (60.53%) and 2wt% (55.26%) but had the same efficiency at 3wt% (73.68%). The optimum weight percentage for PE is 1wt% because of its high efficiency. It is clearly shown that Plant Extract (PE) is a better gas hydrate inhibitor which is gotten from nature and is environmentally friendly unlike Mono Ethylene Glycol (MEG) which is synthetic and toxic to both human and aquatic life. It is therefore recommended for field trial.
{"title":"Evaluation of the Inhibition Efficiency of Plant Extract PE as Gas Hydrate Inhibitor in a Simulated Offshore Environment","authors":"Virtue Urunwo Elechi, S. S. Ikiensikimama, J. Ajienka, O. Akaranta, M. Onyekonwu, O. Okon","doi":"10.2118/198781-MS","DOIUrl":"https://doi.org/10.2118/198781-MS","url":null,"abstract":"\u0000 This present study emphasizes the inhibition capacity of a local inhibitor, Plant Extract (PE) on structure I (sI) gas hydrate. The Plant Extract (PE) was screened using a mini flow loop made of 316 stainless steel of internal diameter of 0.5-inch encased in a 4-inch PVC pipe skid mounted on a metal frame work fitted with pressure and temperature gauges, mixer vessel, pumps and control switches. Pressure and Temperature readings were recorded for 120 minutes. Plots of Pressure and Temperature versus Time for 1, 2 and 3wt% of the local inhibitor alongside Pressure versus Time plot of PE and MEG were done as a way of comparison. Calculations for Inhibition Efficiency (IE) for local inhibitor PE and MEG was also done. 1wt% of the plant extract (PE) had a high inhibition efficiency of 84.21% while 2 and 3wt% had inhibition efficiency of 60.53% and 73.68% respectively. The overall inhibition efficiency of Plant Extract (PE) was higher than that of MEG for 1wt% (60.53%) and 2wt% (55.26%) but had the same efficiency at 3wt% (73.68%). The optimum weight percentage for PE is 1wt% because of its high efficiency. It is clearly shown that Plant Extract (PE) is a better gas hydrate inhibitor which is gotten from nature and is environmentally friendly unlike Mono Ethylene Glycol (MEG) which is synthetic and toxic to both human and aquatic life. It is therefore recommended for field trial.","PeriodicalId":11110,"journal":{"name":"Day 2 Tue, August 06, 2019","volume":"94 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-08-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85384166","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}
Reservoir connectivity remains a critical and growing area of research and application in the petroleum industry, as most discoveries go through development to maturity. This becomes highly imperative for reservoir management decisions in highly fractured compartments or stacked reservoirs with faults across them. In most field cases and especially for a highly faulted region like the Niger Delta, there are some uncertainties around connectivity primarily due to seismic data and resolutions as regards the technology available at acquisition. The primary aim of this work is to use dynamic modelling to ascertain connectivity in mature reservoirs. This work applied the standard workflow for Reservoir Connectivity Analysis (RCA) in evaluating four (4) stacked reservoirs in the RAINBOW field, onshore Niger-Delta using dynamic modelling of the MBAL multi-tank option. Various scenarios were analyzed with the integrated data – geology, production and reservoir pressure history, fluid and rock properties to select the most likely scenario. For this analysis, a new diagnostic plot was introduced for evaluating transmissibility, which improved the clarity in decision making. Using the prevalent economic parameters, a quick evaluation was done to understand the impacts of the reservoir management decisions on the viability of this approach. From the results, two of the four reservoirs are observed to be dynamically connected. The analysis shows that a new perforation extension opportunity is a quick return decision that can yield considerable returns, while new infill opportunities as the optimal decision. Also, the effects of transmissibility on the reservoirs affect the Net Present Values of the decisions. Therefore, this improved workflow approach can be recommended as a quick win when sufficient time and resources are not available for opportunity maturation. Further work is also required to integrate this understanding to build a simulation model for robust benchmarking.
{"title":"Dynamic Modelling for Reservoir Connectivity Analysis in Mature Fields","authors":"O. Ajayi, Sunday Ikienskimama, Emmanuel Mogbolu","doi":"10.2118/198752-MS","DOIUrl":"https://doi.org/10.2118/198752-MS","url":null,"abstract":"\u0000 Reservoir connectivity remains a critical and growing area of research and application in the petroleum industry, as most discoveries go through development to maturity. This becomes highly imperative for reservoir management decisions in highly fractured compartments or stacked reservoirs with faults across them. In most field cases and especially for a highly faulted region like the Niger Delta, there are some uncertainties around connectivity primarily due to seismic data and resolutions as regards the technology available at acquisition. The primary aim of this work is to use dynamic modelling to ascertain connectivity in mature reservoirs. This work applied the standard workflow for Reservoir Connectivity Analysis (RCA) in evaluating four (4) stacked reservoirs in the RAINBOW field, onshore Niger-Delta using dynamic modelling of the MBAL multi-tank option. Various scenarios were analyzed with the integrated data – geology, production and reservoir pressure history, fluid and rock properties to select the most likely scenario. For this analysis, a new diagnostic plot was introduced for evaluating transmissibility, which improved the clarity in decision making. Using the prevalent economic parameters, a quick evaluation was done to understand the impacts of the reservoir management decisions on the viability of this approach. From the results, two of the four reservoirs are observed to be dynamically connected. The analysis shows that a new perforation extension opportunity is a quick return decision that can yield considerable returns, while new infill opportunities as the optimal decision. Also, the effects of transmissibility on the reservoirs affect the Net Present Values of the decisions. Therefore, this improved workflow approach can be recommended as a quick win when sufficient time and resources are not available for opportunity maturation. Further work is also required to integrate this understanding to build a simulation model for robust benchmarking.","PeriodicalId":11110,"journal":{"name":"Day 2 Tue, August 06, 2019","volume":" 4","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-08-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91412975","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}
A machine learning approach to shear sonic log prediction is demonstrated. The results of this approach were compared to that of an approach based on the Greenberg-Castagna empirical method. This approach is based on supervised machine learning and is implemented in MATLAB. While the Greenberg-Castagna method is an empirical method that attempts to predict shear velocity log from compressional velocity log for various pure and composite lithologies, this approach uses, in addition to compressional velocity log as the main predictor, several other logging measurements as predictors including gamma ray, bulk density, neutron, resistivity, porosity and water saturation logs. A dataset which includes wells with recorded shear velocity logs is used to train and validate the machine learning model. A feature selection process is performed to highlight which of the logs would be good predictors of shear velocity (VS). Various regression models are then trained, and the predicted values compared to the actual for the various models by their root-mean-square errors (RMSE), and the model with the smallest RMSE is chosen. Predictions are then carried out on another well within the dataset, which serves as the validation set. The results show improvement in the accuracy of the predictions over the linear regression model based on the Greenberg-Castagna method, as measured by the RMSE. The case study also demonstrates the potential of carrying out shear sonic log prediction in hydrocarbon-bearing intervals, which is a limitation of the Greenberg-Castagna method which only works in brine-saturated rocks. This approach would provide improved accuracy where shear sonic logs are absent and need to be predicted for geomechanics, rock physics and other applications. This is particularly important in older fields where shear sonic logs were never acquired in the older wells.
{"title":"A Machine Learning Approach to Shear Sonic Log Prediction","authors":"I. Bukar, M. B. Adamu, U. Hassan","doi":"10.2118/198764-MS","DOIUrl":"https://doi.org/10.2118/198764-MS","url":null,"abstract":"\u0000 A machine learning approach to shear sonic log prediction is demonstrated. The results of this approach were compared to that of an approach based on the Greenberg-Castagna empirical method. This approach is based on supervised machine learning and is implemented in MATLAB. While the Greenberg-Castagna method is an empirical method that attempts to predict shear velocity log from compressional velocity log for various pure and composite lithologies, this approach uses, in addition to compressional velocity log as the main predictor, several other logging measurements as predictors including gamma ray, bulk density, neutron, resistivity, porosity and water saturation logs. A dataset which includes wells with recorded shear velocity logs is used to train and validate the machine learning model. A feature selection process is performed to highlight which of the logs would be good predictors of shear velocity (VS). Various regression models are then trained, and the predicted values compared to the actual for the various models by their root-mean-square errors (RMSE), and the model with the smallest RMSE is chosen. Predictions are then carried out on another well within the dataset, which serves as the validation set. The results show improvement in the accuracy of the predictions over the linear regression model based on the Greenberg-Castagna method, as measured by the RMSE. The case study also demonstrates the potential of carrying out shear sonic log prediction in hydrocarbon-bearing intervals, which is a limitation of the Greenberg-Castagna method which only works in brine-saturated rocks. This approach would provide improved accuracy where shear sonic logs are absent and need to be predicted for geomechanics, rock physics and other applications. This is particularly important in older fields where shear sonic logs were never acquired in the older wells.","PeriodicalId":11110,"journal":{"name":"Day 2 Tue, August 06, 2019","volume":"33 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-08-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80769644","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. M. Salihu, A. Abubakar, B. Meisam, U. A. Emmanuel, K. Hassan, A. Aminu
Behavioural changes of surfactants due to temperature fluctuations, and its interaction with saline environment, is very common during oil and gas operations. Exhibition of transient or permanent flow behaviour is one form of these changes. Therefore, effect of temperature and ionic concentrations (salinity) on flow behaviour of sodium surfactin was experimentally investigated. ORCADA® software-controlled OFITE viscometer (Model 1100) was used to conduct steady-shear study, at 23–50 °C temperature, 0.1–1.5 molar (M) salt concentrations and 0.025–1.0 % surfactin dosages. Sodium surfactin behaves as non-Newtonian fluid, with a pseudoplastic pattern exhibited in aqueous and 0.25-1.5M saline media. Effect of changes in temperature and salinity on apparent viscosity of surfactin was surfactant-dosage dependent. Furthermore, shear-thickening effect set in at a critical shear rate of 680.9 s-1, signifying flow-induced self-aggregation. Surfactant dosages 0.075 and to a lesser extent 0.1% were minimally affected by changes in temperatures, salinity and rate of shear not exceeding 680.9 s-1. The findings suggest pumpability and dispersion characteristics of the biosurfactant.
{"title":"Effect of Temperature and Salt Concentration on Rheological Behaviour of Surfactin","authors":"S. M. Salihu, A. Abubakar, B. Meisam, U. A. Emmanuel, K. Hassan, A. Aminu","doi":"10.2118/198731-MS","DOIUrl":"https://doi.org/10.2118/198731-MS","url":null,"abstract":"\u0000 Behavioural changes of surfactants due to temperature fluctuations, and its interaction with saline environment, is very common during oil and gas operations. Exhibition of transient or permanent flow behaviour is one form of these changes. Therefore, effect of temperature and ionic concentrations (salinity) on flow behaviour of sodium surfactin was experimentally investigated. ORCADA® software-controlled OFITE viscometer (Model 1100) was used to conduct steady-shear study, at 23–50 °C temperature, 0.1–1.5 molar (M) salt concentrations and 0.025–1.0 % surfactin dosages. Sodium surfactin behaves as non-Newtonian fluid, with a pseudoplastic pattern exhibited in aqueous and 0.25-1.5M saline media. Effect of changes in temperature and salinity on apparent viscosity of surfactin was surfactant-dosage dependent. Furthermore, shear-thickening effect set in at a critical shear rate of 680.9 s-1, signifying flow-induced self-aggregation. Surfactant dosages 0.075 and to a lesser extent 0.1% were minimally affected by changes in temperatures, salinity and rate of shear not exceeding 680.9 s-1. The findings suggest pumpability and dispersion characteristics of the biosurfactant.","PeriodicalId":11110,"journal":{"name":"Day 2 Tue, August 06, 2019","volume":"30 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-08-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85939501","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}
During fit for service or corrosion risk assessments of oil and gas facility systems, a key parameter required to design and implement an effective risk management strategy is visual inspection. This paper explains how using state of the art computer vision and deep learning techniques could address such challenges. We used majorly the python programming language, Tensorflow Application Programming Interface, Resnet deep learning architecture, GPU machines and cloud computing technologies to achieve this. Beyond the challenges of obtaining sufficient corrosion defects data, our final solution is a systematic method that would assist field personnel, facility engineers, service companies and management more accurately detect corrosion defect types and failure modes unbiasedly. This leads to more cost effective and quicker recommendation of preventive or corrective measures.
{"title":"Using Deep Learning and Computer Vision Techniques to Improve Facility Corrosion Risk Management Systems 2.0","authors":"C. Ejimuda, C. Ejimuda","doi":"10.2118/198863-MS","DOIUrl":"https://doi.org/10.2118/198863-MS","url":null,"abstract":"\u0000 During fit for service or corrosion risk assessments of oil and gas facility systems, a key parameter required to design and implement an effective risk management strategy is visual inspection. This paper explains how using state of the art computer vision and deep learning techniques could address such challenges. We used majorly the python programming language, Tensorflow Application Programming Interface, Resnet deep learning architecture, GPU machines and cloud computing technologies to achieve this. Beyond the challenges of obtaining sufficient corrosion defects data, our final solution is a systematic method that would assist field personnel, facility engineers, service companies and management more accurately detect corrosion defect types and failure modes unbiasedly. This leads to more cost effective and quicker recommendation of preventive or corrective measures.","PeriodicalId":11110,"journal":{"name":"Day 2 Tue, August 06, 2019","volume":"80 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-08-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81116990","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}
A new high-pressure high temperature (HP-HT) lab-scale rig involving microbial cultivation of pure bacteria strain under reservoir conditions of up to 200 bar and 200°C has been developed. This was accompanied by an extensive laboratory investigation to establish the mechanisms associated with the production and screening of Lipopeptide from pure Bacillus mojavensis NCIMB 13391 strain for the purpose of enhanced oil recovery (EOR) processes. We report for the first time, thermodynamic standard Gibbs free energy required for the Lipopeptide environment friendly biosurfactant (EFBS) formation (ΔGf°) as -2135.1 J.mol−1, and very low brine salinity water (VLBSW) molarity of 0.5096 mg.l− 1. The produced Lipopeptide biomaterial under anaerobic batch cultivation technique generated CMC values of 2.8 mg.l−1 and 2.7 mg.l−1 in deionised water and VLBSW respectively. The dimensionless molecular weight of the produced Lipopeptide biomaterial is 1423.69 and high spontaneity nature of the biomaterial resulting from a more negative ΔGf° value aided the interfacial tension (IFT) reduction of the heavy crude oil and VLBSW system from 15.71 mN.m−1 to 0.04 mN.m−1 at critical micellisation concentration (CMC) of 2.7 mg.l−1 and 65°C under reservoir confined environment, and 1.76 mN.m−1 at 25°C temperature and 55 bar pressure conditions. However, 2.7 mg.l−1 solution molarity, 65°C temperature and 55 bar pressure are recommended as the optimum recovery pilot molarity, temperature and pressure of the screened heavy crude oil material in low-salinity EOR processes.
{"title":"Development of a New High-Pressure High-Temperature Technology for Advanced Screening of Biosurfactants and Injection of Microbes in Porous Rocks during Low-Salinity EOR Processes","authors":"C. C. Onyemara, Lateef T. Akanji, R. Ebel","doi":"10.2118/198878-MS","DOIUrl":"https://doi.org/10.2118/198878-MS","url":null,"abstract":"\u0000 A new high-pressure high temperature (HP-HT) lab-scale rig involving microbial cultivation of pure bacteria strain under reservoir conditions of up to 200 bar and 200°C has been developed. This was accompanied by an extensive laboratory investigation to establish the mechanisms associated with the production and screening of Lipopeptide from pure Bacillus mojavensis NCIMB 13391 strain for the purpose of enhanced oil recovery (EOR) processes. We report for the first time, thermodynamic standard Gibbs free energy required for the Lipopeptide environment friendly biosurfactant (EFBS) formation (ΔGf°) as -2135.1 J.mol−1, and very low brine salinity water (VLBSW) molarity of 0.5096 mg.l− 1. The produced Lipopeptide biomaterial under anaerobic batch cultivation technique generated CMC values of 2.8 mg.l−1 and 2.7 mg.l−1 in deionised water and VLBSW respectively. The dimensionless molecular weight of the produced Lipopeptide biomaterial is 1423.69 and high spontaneity nature of the biomaterial resulting from a more negative ΔGf° value aided the interfacial tension (IFT) reduction of the heavy crude oil and VLBSW system from 15.71 mN.m−1 to 0.04 mN.m−1 at critical micellisation concentration (CMC) of 2.7 mg.l−1 and 65°C under reservoir confined environment, and 1.76 mN.m−1 at 25°C temperature and 55 bar pressure conditions. However, 2.7 mg.l−1 solution molarity, 65°C temperature and 55 bar pressure are recommended as the optimum recovery pilot molarity, temperature and pressure of the screened heavy crude oil material in low-salinity EOR processes.","PeriodicalId":11110,"journal":{"name":"Day 2 Tue, August 06, 2019","volume":"15 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-08-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87008096","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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