Artificial Intelligence systems utilize a variety of technologies making it possible to produce comprehensive, nonetheless easy-to-use tools, which can be used by Health, Safety and Environment professionals in oil and gas industry. The objective of this paper is to provide an overview of AI opportunities for constantly evolving oil and gas business in addressing such issues as environmental protection. This paper examines a variety of AI applications aimed to provide support to HSE professionals in reviewing big batches of random data and identify important patterns for further planning; develop viable models to assist examination of various event scenarios, predict and mitigate emergencies. As with any data-driven AI tool, the type and amount of data available are perhaps the decisive factors when selecting the AI agent environment. The HSE fields with ample amounts of workable data for machine learning will be reviewed. AI systems utilize a variety of technologies making it possible to produce comprehensive, nonetheless easy-to-use tools, which can be used by HSE professionals in their daily activities. Artificial intelligence technologies today offer a pool of decision-making models for oil and gas industry. The tools developed based on the AI technologies and machine learning can help specialists working in the fields of HSE to advance their efforts in environmental protection, and contribute to mitigating climate change and weather disaster issues, biodiversity conservation, waste reduction, water security, healthy oceans, and clean air. There are over 80 areas in environmental protection initiatives where the AI and ML models are actively used. These tools prove to be more effective in executing routine tasks with higher accuracy and faster completion rates. The AI is also progressing in unsupervised decision-making, which however, raises concerns among the scientists and law-makers as algorithms using historical data may not only incorporate previous discriminations and biases, but reinforce them. Artificial intelligent systems using machine learning are constantly improving in accuracy, presenting an opportunity for constantly growing oil and gas business in improving their environmental compliance activity, and developing a well-praised image of a sustainable community partner.
{"title":"Artificial Intelligence Opportunities for Environmental Protection","authors":"Dayanch Hojageldiyev","doi":"10.2118/198616-ms","DOIUrl":"https://doi.org/10.2118/198616-ms","url":null,"abstract":"\u0000 Artificial Intelligence systems utilize a variety of technologies making it possible to produce comprehensive, nonetheless easy-to-use tools, which can be used by Health, Safety and Environment professionals in oil and gas industry. The objective of this paper is to provide an overview of AI opportunities for constantly evolving oil and gas business in addressing such issues as environmental protection.\u0000 This paper examines a variety of AI applications aimed to provide support to HSE professionals in reviewing big batches of random data and identify important patterns for further planning; develop viable models to assist examination of various event scenarios, predict and mitigate emergencies. As with any data-driven AI tool, the type and amount of data available are perhaps the decisive factors when selecting the AI agent environment. The HSE fields with ample amounts of workable data for machine learning will be reviewed.\u0000 AI systems utilize a variety of technologies making it possible to produce comprehensive, nonetheless easy-to-use tools, which can be used by HSE professionals in their daily activities. Artificial intelligence technologies today offer a pool of decision-making models for oil and gas industry. The tools developed based on the AI technologies and machine learning can help specialists working in the fields of HSE to advance their efforts in environmental protection, and contribute to mitigating climate change and weather disaster issues, biodiversity conservation, waste reduction, water security, healthy oceans, and clean air. There are over 80 areas in environmental protection initiatives where the AI and ML models are actively used. These tools prove to be more effective in executing routine tasks with higher accuracy and faster completion rates. The AI is also progressing in unsupervised decision-making, which however, raises concerns among the scientists and law-makers as algorithms using historical data may not only incorporate previous discriminations and biases, but reinforce them.\u0000 Artificial intelligent systems using machine learning are constantly improving in accuracy, presenting an opportunity for constantly growing oil and gas business in improving their environmental compliance activity, and developing a well-praised image of a sustainable community partner.","PeriodicalId":112955,"journal":{"name":"Day 1 Mon, October 21, 2019","volume":"27 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133252344","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}
Zakariya Abdullah Al Kalbani, Carlos Moreno, Abel Eduardo Agguirre, M. Jahwari, A. Sutherland, Mutaz Elyas
The successful drilling campaign from all aspects is all depending on a robust solution developed during the design phase on the well construction process. This paper describes the advance technical engagement between the operator and integrated drilling services provider to generate an optimum well design for drilling development wells in Sahmah field of block 7, in the south east of Oman. Integrated Drilling Services (IDS) provider in Oman was awarded a contract to drill 10 firmed wells for a national client. One of the most challenging environments in the surface section is to drill and cement highly fractured and caved carbonate formation (UER) which prone to losses as this play a major risk and later deal with problematic shale formation in the same section. Moreover, the client decided to change the scope of some of the development wells and go for exploration pilot hole exploring deeper horizons to evaluate other potential hydrocarbon zones. The engineering team have the opportunity to study the field in depth. As a result of analyzing offset wells data, geological and geomechanical studies, a new well design has been proposed which eliminates one section of the previous well design which was executed on some of the offset wells before. In the same proposal, the intermediate casing setting depth was been extended deeper successfully to accommodate the changes in the scope to explore deeper horizons. The new proposed well design achieved reduction in well construction time and cost for the client enabling reduction in overall Authorization for Expenditure (AFE). This enabled the introduction of new technologies which improved performance. The drilling design consideration process in this paper can be used to provide a valuable insight for future projects where complex technical study in advance is the key to success.
{"title":"Design Optimization for Drilling Development Wells","authors":"Zakariya Abdullah Al Kalbani, Carlos Moreno, Abel Eduardo Agguirre, M. Jahwari, A. Sutherland, Mutaz Elyas","doi":"10.2118/198562-ms","DOIUrl":"https://doi.org/10.2118/198562-ms","url":null,"abstract":"The successful drilling campaign from all aspects is all depending on a robust solution developed during the design phase on the well construction process. This paper describes the advance technical engagement between the operator and integrated drilling services provider to generate an optimum well design for drilling development wells in Sahmah field of block 7, in the south east of Oman. Integrated Drilling Services (IDS) provider in Oman was awarded a contract to drill 10 firmed wells for a national client. One of the most challenging environments in the surface section is to drill and cement highly fractured and caved carbonate formation (UER) which prone to losses as this play a major risk and later deal with problematic shale formation in the same section. Moreover, the client decided to change the scope of some of the development wells and go for exploration pilot hole exploring deeper horizons to evaluate other potential hydrocarbon zones. The engineering team have the opportunity to study the field in depth. As a result of analyzing offset wells data, geological and geomechanical studies, a new well design has been proposed which eliminates one section of the previous well design which was executed on some of the offset wells before. In the same proposal, the intermediate casing setting depth was been extended deeper successfully to accommodate the changes in the scope to explore deeper horizons. The new proposed well design achieved reduction in well construction time and cost for the client enabling reduction in overall Authorization for Expenditure (AFE). This enabled the introduction of new technologies which improved performance. The drilling design consideration process in this paper can be used to provide a valuable insight for future projects where complex technical study in advance is the key to success.","PeriodicalId":112955,"journal":{"name":"Day 1 Mon, October 21, 2019","volume":"37 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114464906","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 objective of this study was to develop tools to analyze the production profile of unconventional gas reservoirs where adsorption is a dominant storage mechanism. Specifically, the research is focused on analyzing the conditions that affect the time needed to achieve peak gas production rate. To this end, we have successfully derived the analytical expressions for the reservoir pressures at which peak gas production occurs under various operating scenarios. The methodology involves the development of a system of generalized two-phase material balance equations for boundary dominated flow in unconventional gas reservoirs where adsorption is a dominant storage mechanism. The resulting analytical ODEs are then solved numerically (Runge-Kutta) which yields a semi-analytical solution for pressure and saturation versus time. Once the pressure and saturations are determined numerically, gas and water production rates, along with their derivatives, are determined analytically and used to analyze the production profiles. Through the analytical derivatives, reservoir and fluid parameters can be modified to observe their effects on the time to peak gas rate. In this study, three different well specifications were investigated (constant flowing well pressure, constant well drawdown, and constant water production rate) with only two of the three well specifications resulting in a peak gas production rate - no peak gas production rate was observed for the water rate specified wells. Furthermore, the developed semi-analytical model, under appropriate conditions, gives results comparable to numerical reservoir simulator. The paper will discuss conditions at which the material balance results are comparable to full reservoir simulation. Through this research, a new material balance method has been developed that can be presented in different domains (pressure, time, and cumulative produced fluids domains). Also, the novel use of derivatives from the generalized material balance equations was applied in this research to analytically and graphically analyze the production profile. Furthermore, in addition to the peak gas production rate, additional inflection points were observed that have not been reported in the current literature.
{"title":"Semi-Analytical Analysis of Peak Production Rates in Unconventional, Boundary-Dominated Gas Reservoirs with Adsorptive Storage","authors":"Abdulla Alzaabi, G. King","doi":"10.2118/198592-ms","DOIUrl":"https://doi.org/10.2118/198592-ms","url":null,"abstract":"\u0000 The objective of this study was to develop tools to analyze the production profile of unconventional gas reservoirs where adsorption is a dominant storage mechanism. Specifically, the research is focused on analyzing the conditions that affect the time needed to achieve peak gas production rate. To this end, we have successfully derived the analytical expressions for the reservoir pressures at which peak gas production occurs under various operating scenarios.\u0000 The methodology involves the development of a system of generalized two-phase material balance equations for boundary dominated flow in unconventional gas reservoirs where adsorption is a dominant storage mechanism. The resulting analytical ODEs are then solved numerically (Runge-Kutta) which yields a semi-analytical solution for pressure and saturation versus time. Once the pressure and saturations are determined numerically, gas and water production rates, along with their derivatives, are determined analytically and used to analyze the production profiles. Through the analytical derivatives, reservoir and fluid parameters can be modified to observe their effects on the time to peak gas rate.\u0000 In this study, three different well specifications were investigated (constant flowing well pressure, constant well drawdown, and constant water production rate) with only two of the three well specifications resulting in a peak gas production rate - no peak gas production rate was observed for the water rate specified wells. Furthermore, the developed semi-analytical model, under appropriate conditions, gives results comparable to numerical reservoir simulator. The paper will discuss conditions at which the material balance results are comparable to full reservoir simulation.\u0000 Through this research, a new material balance method has been developed that can be presented in different domains (pressure, time, and cumulative produced fluids domains). Also, the novel use of derivatives from the generalized material balance equations was applied in this research to analytically and graphically analyze the production profile. Furthermore, in addition to the peak gas production rate, additional inflection points were observed that have not been reported in the current literature.","PeriodicalId":112955,"journal":{"name":"Day 1 Mon, October 21, 2019","volume":"12 4 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132953493","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}
Produced water is inevitable in the life span of a reservoir despite the challenges associated with it. To make an informed decision on economic and engineering design, it is essential to establish post water breakthrough trend to predict water production and to design surface facilities to handle the volume of water that will be produced. Several correlations and models have been proposed in the literature; however, each of the models could solve the problem from which it was derived. Most of the traditional models represent water cut as a function of cumulative oil production or time which is only achievable when accurate water cuts are available. This paper analysis post water breakthrough performance using empirical models. In this proposed method, the water cut (WC) was redefined and plotted against the oil flow rate (Qo). Different models were developed to capture the trends of the plotted graph. It is interesting to note that during water breakthrough, there exist exponential, hyperbolic and harmonic increase in water production throughout the reservoir life span. The model was validated with producing field data and has proven to be robust and can be a reliable tool for estimating water production. The newly developed model in this paper offers an advantage of predicting the corresponding WC at any given Qo and bottom hole pressure.
{"title":"Comprehensive Evaluation of Water Breakthrough With a Novel Method to Estimate Water Production","authors":"D. A. Shehri","doi":"10.2118/198643-ms","DOIUrl":"https://doi.org/10.2118/198643-ms","url":null,"abstract":"\u0000 Produced water is inevitable in the life span of a reservoir despite the challenges associated with it. To make an informed decision on economic and engineering design, it is essential to establish post water breakthrough trend to predict water production and to design surface facilities to handle the volume of water that will be produced. Several correlations and models have been proposed in the literature; however, each of the models could solve the problem from which it was derived. Most of the traditional models represent water cut as a function of cumulative oil production or time which is only achievable when accurate water cuts are available.\u0000 This paper analysis post water breakthrough performance using empirical models. In this proposed method, the water cut (WC) was redefined and plotted against the oil flow rate (Qo). Different models were developed to capture the trends of the plotted graph. It is interesting to note that during water breakthrough, there exist exponential, hyperbolic and harmonic increase in water production throughout the reservoir life span. The model was validated with producing field data and has proven to be robust and can be a reliable tool for estimating water production.\u0000 The newly developed model in this paper offers an advantage of predicting the corresponding WC at any given Qo and bottom hole pressure.","PeriodicalId":112955,"journal":{"name":"Day 1 Mon, October 21, 2019","volume":"83 4 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122775393","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. Ayirala, Zuoli Li, Rubia Mariath, A. AlSofi, Zhenghe Xu, A. Yousef
The conventional experimental techniques used for performance evaluation of enhanced oil recovery (EOR) chemicals, such as polymers and surfactants, have been mostly limited to bulk viscosity, phase behavior/interfacial tension, and thermal stability measurements. Furthermore, fundamental studies exploring the different microscale interactions instigated by the EOR chemicals at the crude oil-water interface are scanty. The objective of this experimental study is to fill this existing knowledge gap and deliver an important understanding on underlying interfacial sciences and their potential implications for oil recovery in chemical EOR. Different microscale interactions of EOR chemicals, at crude oil-water interface, were studied by using a suite of experimental techniques including interfacial shear rheometer, Langmuir trough, and coalescence time measurement apparatus at both ambient (23°C) and elevated (70°C) temperatures. The reservoir crude oil and high salinity injection water (57,000 ppm TDS) were used. Two chemicals, a nonionic surfactant (at 1000 ppm) and a sulfonated polyacrylamide polymer (at 500 ppm and 700 ppm), were chosen since they are tolerant to high salinity and high temperature conditions. Interfacial viscous and elastic moduli (viscoelasticity), interface pressures, interface compression energies, and coalescence time between crude oil droplets are the major experimental data measured. Interfacial shear rheology results showed that surfactant favorably reduced the viscoelasticity of crude oil-water interface by decreasing both elastic and viscous modulus to soften the interfacial film. Polymer in brine either alone or together with surfactant increased viscous and elastic modulus at the oil-water interface thereby contributing to interfacial film rigidity. Interfacial pressures with polymer remained almost in the same order of magnitude as the high salinity brine. In contrast, a significant reduction in interfacial pressures with surfactant was observed. The interface compression energies indicated the same trend and were reduced by about two orders of magnitude when surfactant is added to the brine. The surfactant was also able to retain similar interface behavior under compression even in the presence of polymer. The coalescence times between crude oil droplets were increased by polymer whereas substantially decreased by the surfactant. These consistent findings from different experimental techniques demonstrated the adverse interactions of polymer at crude oil-water interface to result in more rigid films, while confirming the high efficiency of surfactant to soften the interfacial film, promote the oil droplets coalescence and mobilize substantial amounts of residual oil in chemical EOR. This experimental study, for the first time, characterized the microscale interactions of surfactant/polymer chemicals at crude-oil water interface. The applicability of several interfacial experimental techniques has been demonstrate
{"title":"Microscale Interactions of Surfactant and Polymer Chemicals at Crude Oil-Water Interface for Enhanced Oil Recovery","authors":"S. Ayirala, Zuoli Li, Rubia Mariath, A. AlSofi, Zhenghe Xu, A. Yousef","doi":"10.2118/198574-ms","DOIUrl":"https://doi.org/10.2118/198574-ms","url":null,"abstract":"\u0000 The conventional experimental techniques used for performance evaluation of enhanced oil recovery (EOR) chemicals, such as polymers and surfactants, have been mostly limited to bulk viscosity, phase behavior/interfacial tension, and thermal stability measurements. Furthermore, fundamental studies exploring the different microscale interactions instigated by the EOR chemicals at the crude oil-water interface are scanty. The objective of this experimental study is to fill this existing knowledge gap and deliver an important understanding on underlying interfacial sciences and their potential implications for oil recovery in chemical EOR.\u0000 Different microscale interactions of EOR chemicals, at crude oil-water interface, were studied by using a suite of experimental techniques including interfacial shear rheometer, Langmuir trough, and coalescence time measurement apparatus at both ambient (23°C) and elevated (70°C) temperatures. The reservoir crude oil and high salinity injection water (57,000 ppm TDS) were used. Two chemicals, a nonionic surfactant (at 1000 ppm) and a sulfonated polyacrylamide polymer (at 500 ppm and 700 ppm), were chosen since they are tolerant to high salinity and high temperature conditions. Interfacial viscous and elastic moduli (viscoelasticity), interface pressures, interface compression energies, and coalescence time between crude oil droplets are the major experimental data measured.\u0000 Interfacial shear rheology results showed that surfactant favorably reduced the viscoelasticity of crude oil-water interface by decreasing both elastic and viscous modulus to soften the interfacial film. Polymer in brine either alone or together with surfactant increased viscous and elastic modulus at the oil-water interface thereby contributing to interfacial film rigidity. Interfacial pressures with polymer remained almost in the same order of magnitude as the high salinity brine. In contrast, a significant reduction in interfacial pressures with surfactant was observed. The interface compression energies indicated the same trend and were reduced by about two orders of magnitude when surfactant is added to the brine. The surfactant was also able to retain similar interface behavior under compression even in the presence of polymer. The coalescence times between crude oil droplets were increased by polymer whereas substantially decreased by the surfactant. These consistent findings from different experimental techniques demonstrated the adverse interactions of polymer at crude oil-water interface to result in more rigid films, while confirming the high efficiency of surfactant to soften the interfacial film, promote the oil droplets coalescence and mobilize substantial amounts of residual oil in chemical EOR.\u0000 This experimental study, for the first time, characterized the microscale interactions of surfactant/polymer chemicals at crude-oil water interface. The applicability of several interfacial experimental techniques has been demonstrate","PeriodicalId":112955,"journal":{"name":"Day 1 Mon, October 21, 2019","volume":"35 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131903357","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}
Field presented here is giant heterogeneous carbonate field consist of multi-stacked reservoirs, located in offshore Abu Dhabi. It consists of a very large rich gas cap with oil rim. Current development plan is oil production from oil rim with peripheral water injection & crestal gas injection. Long Term Development Plan "LTDP" of field consists of co-development of oil rim (through water injection at GOC) and gas cap (through partial gas recycling) to maximize oil, condensate & gas value. Details of LTDP are in Ref. 7. To further maximize condensate value, mid-term plan is complete gas recycling by production of rich gas through gas cap producer located downdip of structure and injection of dry gas through gas injector located in the crest. To de-risk midterm plan, a gas cap producer pilot has been drilled in one of prolific reservoir. Main objectives of gas producer pilot were to reduce uncertainty of CGR, assess gas well capacity & assess gas offtake impact on oil rim. This paper presents optimization of gas cap development in terms of number of wells, trajectory, location & completion based on learning of gas cap pilot. Literature data indicate that below dew point pressure, gas condensate reservoirs exhibit growth of a condensate bank around the wellbore, which effectively reduce the relative permeability to gas flow & well capacity. Flow in near wellbore region is also impacted by saturation dependent inertial forces (non-Darcy flow). On the other hand at high capillary number improvement in gas relative permeability counteracts the PI reduction. All this effects have been considered in gas cap development. In this study using a fit for purpose sector model extracted from full field model, all the three phenomenon's non-Darcy effect, condensate blockage and relative permeability improvement at higher capillary number has been studied for different well trajectories such as vertical well, deviated well and horizontal well. Based on simulation results horizontal well was chosen for piloting to minimize impact of condensate blockage, gas turbulent effect and produce the condensate reservoir more efficiently. Sector model was fine-tuned based on pilot results which were further upscaled in the full field simulation. Based on pilot learning well trajectory, location & completion has been optimized for different flow units which leads to significant cost saving.
{"title":"Optimization Of Large Gas Cap Development Plan Though Pilot Learning Leading to Significant Cost Saving","authors":"Pawan Agrawal, O. Keshtta, E. Draoui","doi":"10.2118/198598-ms","DOIUrl":"https://doi.org/10.2118/198598-ms","url":null,"abstract":"\u0000 Field presented here is giant heterogeneous carbonate field consist of multi-stacked reservoirs, located in offshore Abu Dhabi. It consists of a very large rich gas cap with oil rim. Current development plan is oil production from oil rim with peripheral water injection & crestal gas injection. Long Term Development Plan \"LTDP\" of field consists of co-development of oil rim (through water injection at GOC) and gas cap (through partial gas recycling) to maximize oil, condensate & gas value. Details of LTDP are in Ref. 7. To further maximize condensate value, mid-term plan is complete gas recycling by production of rich gas through gas cap producer located downdip of structure and injection of dry gas through gas injector located in the crest.\u0000 To de-risk midterm plan, a gas cap producer pilot has been drilled in one of prolific reservoir. Main objectives of gas producer pilot were to reduce uncertainty of CGR, assess gas well capacity & assess gas offtake impact on oil rim. This paper presents optimization of gas cap development in terms of number of wells, trajectory, location & completion based on learning of gas cap pilot.\u0000 Literature data indicate that below dew point pressure, gas condensate reservoirs exhibit growth of a condensate bank around the wellbore, which effectively reduce the relative permeability to gas flow & well capacity. Flow in near wellbore region is also impacted by saturation dependent inertial forces (non-Darcy flow). On the other hand at high capillary number improvement in gas relative permeability counteracts the PI reduction. All this effects have been considered in gas cap development.\u0000 In this study using a fit for purpose sector model extracted from full field model, all the three phenomenon's non-Darcy effect, condensate blockage and relative permeability improvement at higher capillary number has been studied for different well trajectories such as vertical well, deviated well and horizontal well. Based on simulation results horizontal well was chosen for piloting to minimize impact of condensate blockage, gas turbulent effect and produce the condensate reservoir more efficiently. Sector model was fine-tuned based on pilot results which were further upscaled in the full field simulation. Based on pilot learning well trajectory, location & completion has been optimized for different flow units which leads to significant cost saving.","PeriodicalId":112955,"journal":{"name":"Day 1 Mon, October 21, 2019","volume":"36 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114577974","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}
Adib Mahfuz A Rahman, H. Bakar, G DalyKerry, Adhi Naharindra, Suman Kumar, N. Baharuddin, Ahmed Abdelatty Abbas Ibrahim
The use of oriented perforation as a means of sand control technique has been adopted by many operators in industry. Two low angle wells completed in D field offshore Sarawak, Malaysia with moderate to weak rock strength quality required this method not only to limit the sand production but also to sustain the minimum production of 2500bopd each. Based on onset sand production analysis, reservoir M is predicted to have sand production in the direction of a maximum stress of 135degrees from true north. The wells then are suggested to be shot 0-180degree parallel to maximum stress and it saved the expense of no installation of downhole sand exclusion. This paper outlines the perforation analysis conducted to design the optimum perforation using Tubing Conveyed Perforating (TCP) Gun with Dynamic Underbalance (DUB) that effectively clean the newly created perforations. The operational approach applied to overcome the challenge of achieving desired orientation in almost vertical deviation wells by positioning electronic gyroscope siting on Universal Bottom Hole Orientation (UBHO) sub is also discussed in this paper. The available centralization solutions in market are limited to 30° degrees well inclination with 5°accuracies at three times more cost than conventional TCP. The proposal of oriented perforation at both slanted wells significantly saved lot of project economic and proved as effective sand control method, so far the production target is achieved and maintained with no record of sand production at field. Two newly drilled and completed wells located in offshore Sarawak, Malaysia required oriented perforation with dynamic underbalance using Tubing Conveyed Perforating (TCP) guns. The reservoir quality was weak to moderate rock strength with expected sand production in the direction of a maximum stress (135 degrees from true north) within the nearly vertical wellbore. To limit the sand production, the requirement was to shoot 0-180 degree guns parallel to maximum stress, to save the expense of any sand exclusion method. Another requirement was to use Dynamic Underbalance (DUB) to properly clean perforations, reduce skin, and maximize production. The objective was to achieve a minimum production of 2500 BPD. From Geo-mechanic study, in deviated well, the orientation of perforation is aligned with the trend of maximum horizontal stress. Based on breakout analysis, Shmax direction is 135° from the North. The expected production rate can be achieved with Oriented Perforation even at 0 deg phasing and PI reduced from 55 STB/day/psi to 38 STB/day/psi based on Figure 1 below. The studies conducted on Field D available data concluded that sanding risk is very low with Cased & Oriented Perforation strategy.
{"title":"Oriented Perforation using Tubing Conveyed Perforating TCP Gun with Dynamic Underbalance DUB as Sand Control Method in Low Angle Wells, Offshore Sarawak, Malaysia.","authors":"Adib Mahfuz A Rahman, H. Bakar, G DalyKerry, Adhi Naharindra, Suman Kumar, N. Baharuddin, Ahmed Abdelatty Abbas Ibrahim","doi":"10.2118/198678-ms","DOIUrl":"https://doi.org/10.2118/198678-ms","url":null,"abstract":"\u0000 The use of oriented perforation as a means of sand control technique has been adopted by many operators in industry. Two low angle wells completed in D field offshore Sarawak, Malaysia with moderate to weak rock strength quality required this method not only to limit the sand production but also to sustain the minimum production of 2500bopd each. Based on onset sand production analysis, reservoir M is predicted to have sand production in the direction of a maximum stress of 135degrees from true north. The wells then are suggested to be shot 0-180degree parallel to maximum stress and it saved the expense of no installation of downhole sand exclusion. This paper outlines the perforation analysis conducted to design the optimum perforation using Tubing Conveyed Perforating (TCP) Gun with Dynamic Underbalance (DUB) that effectively clean the newly created perforations. The operational approach applied to overcome the challenge of achieving desired orientation in almost vertical deviation wells by positioning electronic gyroscope siting on Universal Bottom Hole Orientation (UBHO) sub is also discussed in this paper. The available centralization solutions in market are limited to 30° degrees well inclination with 5°accuracies at three times more cost than conventional TCP. The proposal of oriented perforation at both slanted wells significantly saved lot of project economic and proved as effective sand control method, so far the production target is achieved and maintained with no record of sand production at field.\u0000 Two newly drilled and completed wells located in offshore Sarawak, Malaysia required oriented perforation with dynamic underbalance using Tubing Conveyed Perforating (TCP) guns. The reservoir quality was weak to moderate rock strength with expected sand production in the direction of a maximum stress (135 degrees from true north) within the nearly vertical wellbore. To limit the sand production, the requirement was to shoot 0-180 degree guns parallel to maximum stress, to save the expense of any sand exclusion method. Another requirement was to use Dynamic Underbalance (DUB) to properly clean perforations, reduce skin, and maximize production. The objective was to achieve a minimum production of 2500 BPD.\u0000 From Geo-mechanic study, in deviated well, the orientation of perforation is aligned with the trend of maximum horizontal stress. Based on breakout analysis, Shmax direction is 135° from the North. The expected production rate can be achieved with Oriented Perforation even at 0 deg phasing and PI reduced from 55 STB/day/psi to 38 STB/day/psi based on Figure 1 below. The studies conducted on Field D available data concluded that sanding risk is very low with Cased & Oriented Perforation strategy.","PeriodicalId":112955,"journal":{"name":"Day 1 Mon, October 21, 2019","volume":"39 3","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"113962751","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 is a combined review of the literature on the safety culture in the offshore industry as a whole and safety in the offshore access industry. As well as a review on best practices to incorporate new technologies and systems into an organisation. Safe offshore access is a challenge that all players in the offshore energy industry face, and setting the standards requires the continuous implementation of new technologies and higher managements' hands-on involvement in its implementation. Finally, this paper looks at three key criteria that could bring the safety culture from being responsive to preventive and ultimately to proactive. It does so by evaluating the safety culture using the Hudson's safety culture ladder. In the end, it is always important to note that safety is the responsibility of everyone.
{"title":"Setting the Standard for Safety in the Offshore Access Industry","authors":"M. Nacheva, Krissi Silianova, Tim Mulders","doi":"10.2118/198600-ms","DOIUrl":"https://doi.org/10.2118/198600-ms","url":null,"abstract":"\u0000 This paper is a combined review of the literature on the safety culture in the offshore industry as a whole and safety in the offshore access industry. As well as a review on best practices to incorporate new technologies and systems into an organisation. Safe offshore access is a challenge that all players in the offshore energy industry face, and setting the standards requires the continuous implementation of new technologies and higher managements' hands-on involvement in its implementation.\u0000 Finally, this paper looks at three key criteria that could bring the safety culture from being responsive to preventive and ultimately to proactive. It does so by evaluating the safety culture using the Hudson's safety culture ladder. In the end, it is always important to note that safety is the responsibility of everyone.","PeriodicalId":112955,"journal":{"name":"Day 1 Mon, October 21, 2019","volume":"30 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122465226","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}
Dope-free technology is a dry multilayer coating that provides key advantages during the make-up process of the connections under extreme conditions compared to doped technology. The dry coating doesn't need a reapplication after the repeated break and make of connection, meanwhile providing more consistent make-up performance. (Castineiras, T., Nunez, A., Gallo, E., and Carcagno, G. E. 2009) The use of dope-free Technology tubulars in offshore and onshore operations has been increasingly adopted by multiple operators since the first running that took place in the North Sea in 2003. Dope-free tubulars replace the storage and running pipe dope historically used in casing and tubing by a dry coating applied on pipe threads in an industrial controlled environment. The elimination of dope greatly simplifies the supply chain process involved in preparing casing and tubing for onshore and offshore wells, thus increasing efficiency and safety and lessening the environmental impact of the process. The benefits of dope-free technology can be divided in 4 main macro-areas: Environmental benefits, health and safety benefits, improved well productivity and improved operational performance. Dope-free technology does not have any environmental impact: the compound layers are thin films of dried chemicals and they are not displaced into the tubes nor into the environment during the offshore installation of the pipes. According to a study performed by Det Norske Veritas (DNV, i.e. a Norwegian classification society with the objective of "Safeguarding life, property, and the environment"), dope-free technology represents a significant step forward for the environmental protection.Concerning H&S benefits, dope-free technology brings a significant improvement. This comes as a result of eliminating certain operations required when using standard material (with dope) that will expose employees to risks: the exposure of the workers to potential incidents/accidents risks related to tubulars handling is significantly reduced. According OHSAS 18001: 2007, the elimination of the task is the first action in order to reduce and control the risk.Dope-free technology allows many operational benefits during the field assessment: all these benefits could assure an increased efficiency (i.e. faster installation, reduced number of rejects and re-make ups, elimination of risk related to improper thread compound application, no need of cleaning storage compound) and an increased reliability (i.e. more consistent make-up operations and no improper dope application caused by human errors).A tubing string that has been over-doped, the excess of dope might result in reduction of permeability and blockage of flow path due to plugging of porous formation. In addition, the excess lublicant can clog valves, sandscreens and heads of the perforating guns. Nevetheless, the biggest problem that can be due to excess of dope is on the near-well zone because thread compounds are not easily so
无掺杂技术是一种干燥的多层涂层，与掺杂技术相比，它在极端条件下的连接连接过程中具有关键优势。干性涂料不需要在多次断开和连接后重新涂抹，同时提供更一致的化妆性能。(Castineiras, T.， Nunez, A.， Gallo, E.和Carcagno, G.， 2009)自2003年在北海首次使用无添加剂技术管柱以来，越来越多的运营商在海上和陆上作业中使用无添加剂技术管柱。在工业控制环境下，无涂料管通过在管道螺纹上涂干涂层，取代了套管和油管中使用的储存和下入管道涂料。涂料的消除极大地简化了为陆上和海上油井准备套管和油管的供应链过程，从而提高了效率和安全性，并减少了该过程对环境的影响。无掺杂技术的好处可以分为4个主要的宏观领域:环境效益、健康和安全效益、提高油井产能和改善运营绩效。无兴奋剂技术不会对环境产生任何影响:化合物层是干燥化学品的薄膜，在海上安装管道期间，它们不会转移到管道中或进入环境中。根据挪威船级社(DNV，即以“保护生命、财产和环境”为目标的挪威船级社)的一项研究，无毒品技术代表着环境保护向前迈出的重要一步。在H&S效益方面，无毒品技术带来了显著的改善。这是由于消除了使用标准材料(含涂料)时需要的某些操作，这些操作会使员工面临风险:工人暴露于与管处理相关的潜在事件/事故风险大大降低。根据OHSAS 18001: 2007，消除任务是降低和控制风险的第一步。在现场评估过程中，无掺杂技术带来了许多操作优势:所有这些优势都可以确保提高效率(即更快的安装，减少拒绝和重新组装的数量，消除与螺纹化合物使用不当相关的风险，不需要清洗储存化合物)和提高可靠性(即更一致的上料操作，没有人为错误导致的不当涂料应用)。如果一根管柱中掺杂过多，过量的掺杂可能会导致渗透性降低，并因多孔地层堵塞而导致流道堵塞。此外，多余的润滑油会堵塞阀门、防砂网和射孔枪的头部。然而，由于螺纹化合物不容易被水基溶剂和油基溶剂溶解，因此过量涂料可能造成的最大问题是在近井区域。(De Franceschi, E.， Castineiras, T.， Benedetto, F.， Funes, A.， Figini, F.， and Economides, M. J. 2013)这就是为什么无毒品技术可以为油井产能和后期作业带来重要好处的主要原因。
{"title":"Dope Free Technology Advantages for Drilling and Completion Operations","authors":"P. Novelli, Simone Malesani, Zhambul Turgunbayev","doi":"10.2118/198677-ms","DOIUrl":"https://doi.org/10.2118/198677-ms","url":null,"abstract":"\u0000 Dope-free technology is a dry multilayer coating that provides key advantages during the make-up process of the connections under extreme conditions compared to doped technology. The dry coating doesn't need a reapplication after the repeated break and make of connection, meanwhile providing more consistent make-up performance. (Castineiras, T., Nunez, A., Gallo, E., and Carcagno, G. E. 2009)\u0000 The use of dope-free Technology tubulars in offshore and onshore operations has been increasingly adopted by multiple operators since the first running that took place in the North Sea in 2003. Dope-free tubulars replace the storage and running pipe dope historically used in casing and tubing by a dry coating applied on pipe threads in an industrial controlled environment. The elimination of dope greatly simplifies the supply chain process involved in preparing casing and tubing for onshore and offshore wells, thus increasing efficiency and safety and lessening the environmental impact of the process.\u0000 The benefits of dope-free technology can be divided in 4 main macro-areas: Environmental benefits, health and safety benefits, improved well productivity and improved operational performance. Dope-free technology does not have any environmental impact: the compound layers are thin films of dried chemicals and they are not displaced into the tubes nor into the environment during the offshore installation of the pipes. According to a study performed by Det Norske Veritas (DNV, i.e. a Norwegian classification society with the objective of \"Safeguarding life, property, and the environment\"), dope-free technology represents a significant step forward for the environmental protection.Concerning H&S benefits, dope-free technology brings a significant improvement. This comes as a result of eliminating certain operations required when using standard material (with dope) that will expose employees to risks: the exposure of the workers to potential incidents/accidents risks related to tubulars handling is significantly reduced. According OHSAS 18001: 2007, the elimination of the task is the first action in order to reduce and control the risk.Dope-free technology allows many operational benefits during the field assessment: all these benefits could assure an increased efficiency (i.e. faster installation, reduced number of rejects and re-make ups, elimination of risk related to improper thread compound application, no need of cleaning storage compound) and an increased reliability (i.e. more consistent make-up operations and no improper dope application caused by human errors).A tubing string that has been over-doped, the excess of dope might result in reduction of permeability and blockage of flow path due to plugging of porous formation. In addition, the excess lublicant can clog valves, sandscreens and heads of the perforating guns. Nevetheless, the biggest problem that can be due to excess of dope is on the near-well zone because thread compounds are not easily so","PeriodicalId":112955,"journal":{"name":"Day 1 Mon, October 21, 2019","volume":"177 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121522411","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}
Javier Torres, S. Moslim, Prashant Gohel, Awais Warraich, T. Toki, I. Abdelkarim, A. Harbi, Ameen Al-Kasasbeh, D. Beaman, T. Takanishi, N. Mukai, S. Ali, Y. A. Hammadi, F. A. Ameri, Ali Eissa Al Mahri, Adel Al Marzouqi, Mohamed R. Al Zaabi, Yousif Al Katheeri, M. Oviedo, A. Ibrahim
Driving efficiency to ensure cost and risk reduction in well operations is paramount for any operating company; to achieve this, the main objective was to implement a continuous improvement process that measures performance to then improve it, acquiring lessons learned and finally implement new technologies to reduce non-productive time, invisible loss time and push the technical limit to the limit. The first step was to measure the current performance to determine average and best references to compare against. The drilling operations and engineering teams defined KPIs for each well type and respective sections and activities involving all levels of the organization including every individual, ensuring effective communication inclusive of Rig Crew and Service Providers. The initial KPIs were defined, discussed, validated and agreed by both operations and engineering management, all engineers were informed and challenged to measure their performance against KPIs. Once new records were achieved, a workflow to document best practices initiated, once identified, validated and documented, becoming the new standards. Similarly, once average performance was not achieved, a ‘Lessons Learned’ workflow was initiated. Aiming to get the team engaged a communication protocol of the Highlights and Lowlights was put in place, including recognition during operations meeting and emails. The primary results of the deployment of this initiative include the delivery of a 10% additional well count compared to the initial year's plan. An overall improvement of the overall Drilling and Completion Performance was also noted. An important improvement of the overall Rate of Penetration (ROP) was observed, as one of the key performance indicators. It was also notice a considerable reduction of the Flat time. New practices for losses mitigation in hazardous areas were stablished. The lower completion design was enhanced. The upper completion design and utilize Dual Hydraulic Packer in Oil producer well was optimized. Finally, the 1st Maximum Reservoir Contact Well was completed for two of the three Fields in the Team. The added value achieved by the implementation of these innovative practices includes the implementation of the KPI Gauges as a visual instrument to be used on daily operations meeting by the engineers and management, to quickly and effectively understand performance and improvement in multiple dimensions. Additionally, the implementation of a continuous improvement mind-set, focus in introducing changes gradually instead of radically to ensure a soft and solid adoption embraced by all team members. Finally, the improvement of the office-field communications, including a sense of ownership and achievement for each goal to achieve and record to break, to the point that every colleague involved in a specific operation, independently of their organization (Operator, Contractor or Service Company) is equally committed and engaged.
{"title":"Innovative Approach Ensuring Continuous Improvement in Well Design and Operations Based on Performance Tracking, Lessons Learned and Implementation of New Technologies, Pushing the Technical Limit to Reduce Costs and Risks","authors":"Javier Torres, S. Moslim, Prashant Gohel, Awais Warraich, T. Toki, I. Abdelkarim, A. Harbi, Ameen Al-Kasasbeh, D. Beaman, T. Takanishi, N. Mukai, S. Ali, Y. A. Hammadi, F. A. Ameri, Ali Eissa Al Mahri, Adel Al Marzouqi, Mohamed R. Al Zaabi, Yousif Al Katheeri, M. Oviedo, A. Ibrahim","doi":"10.2118/198560-ms","DOIUrl":"https://doi.org/10.2118/198560-ms","url":null,"abstract":"\u0000 Driving efficiency to ensure cost and risk reduction in well operations is paramount for any operating company; to achieve this, the main objective was to implement a continuous improvement process that measures performance to then improve it, acquiring lessons learned and finally implement new technologies to reduce non-productive time, invisible loss time and push the technical limit to the limit.\u0000 The first step was to measure the current performance to determine average and best references to compare against. The drilling operations and engineering teams defined KPIs for each well type and respective sections and activities involving all levels of the organization including every individual, ensuring effective communication inclusive of Rig Crew and Service Providers. The initial KPIs were defined, discussed, validated and agreed by both operations and engineering management, all engineers were informed and challenged to measure their performance against KPIs. Once new records were achieved, a workflow to document best practices initiated, once identified, validated and documented, becoming the new standards. Similarly, once average performance was not achieved, a ‘Lessons Learned’ workflow was initiated. Aiming to get the team engaged a communication protocol of the Highlights and Lowlights was put in place, including recognition during operations meeting and emails.\u0000 The primary results of the deployment of this initiative include the delivery of a 10% additional well count compared to the initial year's plan. An overall improvement of the overall Drilling and Completion Performance was also noted. An important improvement of the overall Rate of Penetration (ROP) was observed, as one of the key performance indicators.\u0000 It was also notice a considerable reduction of the Flat time. New practices for losses mitigation in hazardous areas were stablished. The lower completion design was enhanced. The upper completion design and utilize Dual Hydraulic Packer in Oil producer well was optimized. Finally, the 1st Maximum Reservoir Contact Well was completed for two of the three Fields in the Team.\u0000 The added value achieved by the implementation of these innovative practices includes the implementation of the KPI Gauges as a visual instrument to be used on daily operations meeting by the engineers and management, to quickly and effectively understand performance and improvement in multiple dimensions. Additionally, the implementation of a continuous improvement mind-set, focus in introducing changes gradually instead of radically to ensure a soft and solid adoption embraced by all team members. Finally, the improvement of the office-field communications, including a sense of ownership and achievement for each goal to achieve and record to break, to the point that every colleague involved in a specific operation, independently of their organization (Operator, Contractor or Service Company) is equally committed and engaged.","PeriodicalId":112955,"journal":{"name":"Day 1 Mon, October 21, 2019","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130514977","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}
京公网安备 11010802042870号
京ICP备2023020795号-1
扫码关注我们
求助内容：
应助结果提醒方式：