Tao Zhang, Xiangfang Li, Zhilin Cheng, Minxia He, Ying Yin, Qing Liu
Shale, as the "tight" rock with abundant nanopores, exhibits extremely low permeability on the order of micro-nanodarcy. The classic Darcy law, being widely and successfully used in developing the oil in conventional deposits, becomes insufficient for that in deposits of the shale. In this work, on the basis of molecular dynamic simulation data available in the literature, a model for oil transport through a single nanopore is established considering the boundary slip and the varying viscosity of the confined oil. The results show that, to accurately predict the oil transport properties in inorganic and organic nanopores, the viscosity correction for the confined oil transport in the nanopores is necessary. The oil transport capability in organic nanopores is greatly enhanced compared with that predicted by the no-slip Poiseuille equation, significantly enhancing the flow capability in the scale of nanoporous media, while the small slip length in the inorganic matter (IOM) has neglected effect. This implies that the greater concentration of drilling activity needs to be implemented in the region with higher TOC, where there is the "sweets spots" from the point of oil transport.
{"title":"The Transport Behavior of Liquid Hydrocarbon in Shale Nanopores","authors":"Tao Zhang, Xiangfang Li, Zhilin Cheng, Minxia He, Ying Yin, Qing Liu","doi":"10.2118/195127-MS","DOIUrl":"https://doi.org/10.2118/195127-MS","url":null,"abstract":"\u0000 Shale, as the \"tight\" rock with abundant nanopores, exhibits extremely low permeability on the order of micro-nanodarcy. The classic Darcy law, being widely and successfully used in developing the oil in conventional deposits, becomes insufficient for that in deposits of the shale. In this work, on the basis of molecular dynamic simulation data available in the literature, a model for oil transport through a single nanopore is established considering the boundary slip and the varying viscosity of the confined oil. The results show that, to accurately predict the oil transport properties in inorganic and organic nanopores, the viscosity correction for the confined oil transport in the nanopores is necessary. The oil transport capability in organic nanopores is greatly enhanced compared with that predicted by the no-slip Poiseuille equation, significantly enhancing the flow capability in the scale of nanoporous media, while the small slip length in the inorganic matter (IOM) has neglected effect. This implies that the greater concentration of drilling activity needs to be implemented in the region with higher TOC, where there is the \"sweets spots\" from the point of oil transport.","PeriodicalId":11031,"journal":{"name":"Day 4 Thu, March 21, 2019","volume":"33 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86198520","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}
Fracture Robots (FracBots) prototype has been successfully designed, developed, fabricated and tested in the laboratory. They are magnetic induction (MI)-based wireless sensor nodes that have the inter-node wireless communication, sensing and localization estimation capabilities. FracBots are miniature devices that can operate as wireless underground sensor networks (WUSNs) inside hydraulic fractures to collect and communicate important data and generate real-time mapping. The energy source of the FracBots is a major challenge since the operational environment is the hydraulic fractures which impose a restriction on the size that doesn't allow enough space for the battery. In addition, the capability to extract the energy from a designate source is another key-role feature that has to be a function of the FracBots. In this regard, energy consumption analysis and evaluation has been done to ensure that all the FracBots have the required energy to work properly during the operation inside the hydraulic fractures. The electronic design of the FracBots must be highly efficient and capable of dramatically reducing power consumption. Thus, FracBots design is composed of ultra-low power electronic chips that enable a switch among an active mode, a deep sleep mode and a shutdown mode with automatic wake-up features (Low Power Modes (LPMs). Also, it includes an energy management unit that harvests surplus power stemming from the base station. This feature reduces the power consumption and ensure continuous operation. Based on our energy model and electronic design, deep analysis of the harvested and consumed energy is conducted in a laboratory testbed. Results of this study show the capability of the FracBots to harvest the required energy to operate and perform all the communications and sensing functionalities. Using ultra-low power electronic chips based on ferromagnetic technology (FRAM) and energy management unit reduce the power consumption of the FracBots by 50% at least.
{"title":"FracBots: Overview and Energy Consumption Analysis","authors":"A. Alshehri, C. H. Martins","doi":"10.2118/194945-MS","DOIUrl":"https://doi.org/10.2118/194945-MS","url":null,"abstract":"\u0000 Fracture Robots (FracBots) prototype has been successfully designed, developed, fabricated and tested in the laboratory. They are magnetic induction (MI)-based wireless sensor nodes that have the inter-node wireless communication, sensing and localization estimation capabilities. FracBots are miniature devices that can operate as wireless underground sensor networks (WUSNs) inside hydraulic fractures to collect and communicate important data and generate real-time mapping. The energy source of the FracBots is a major challenge since the operational environment is the hydraulic fractures which impose a restriction on the size that doesn't allow enough space for the battery. In addition, the capability to extract the energy from a designate source is another key-role feature that has to be a function of the FracBots. In this regard, energy consumption analysis and evaluation has been done to ensure that all the FracBots have the required energy to work properly during the operation inside the hydraulic fractures. The electronic design of the FracBots must be highly efficient and capable of dramatically reducing power consumption. Thus, FracBots design is composed of ultra-low power electronic chips that enable a switch among an active mode, a deep sleep mode and a shutdown mode with automatic wake-up features (Low Power Modes (LPMs). Also, it includes an energy management unit that harvests surplus power stemming from the base station. This feature reduces the power consumption and ensure continuous operation. Based on our energy model and electronic design, deep analysis of the harvested and consumed energy is conducted in a laboratory testbed. Results of this study show the capability of the FracBots to harvest the required energy to operate and perform all the communications and sensing functionalities. Using ultra-low power electronic chips based on ferromagnetic technology (FRAM) and energy management unit reduce the power consumption of the FracBots by 50% at least.","PeriodicalId":11031,"journal":{"name":"Day 4 Thu, March 21, 2019","volume":"11 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84854120","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. Ullah, Abdulqawi Al-Fakih, M. Almomen, Robert Famiev, A. S. Alatiyyah, Taimour Al Sharif
In one of the largest oil fields in Middle East, the typical well design is to set the conductor just 40 ft below the ground, the surface casing 100 ft inside next competent formation due to shallow total loss zone below the conductor and the intermediate casing in the first competent formation before entering the reservoirs interval. The intermediate section includes a combination of formations that have total losses zones and extremely unstable shales, especially when drilled with total losses. In most cases, encountering lost circulation results in formation collapse. The severity of the formation collapse risk in this section ranges from simple tights spots cleared with reaming up and down to stuck pipes, sidetracks and in several cases plug and abandonment of wells. To reduce the likelihood and severity of this risk, there was a need to review the casing seats to isolate unstable formations before entering the intermediate loss zones. A detailed study was carried out where diverse options were analyzed, including adding a casing string and changing casing seats of existing casing strings. The study concluded that keeping the same number of casing strings and deepening only the surface casing seat as close as possible to the intermediate loss zone, covering the entire unstable formation but not entering the intermediate loss zone, would be the most efficient solution. Experts supported this change based on the principle that dealing with an unstable formation when it is below the loss zone is easier than when the same formation is above the loss zone. The new casing seat choice has been successfully implemented at over 100 wells, with 100% success ending the borehole instability problems. Since then there has been no sidetrack or location plugged and abandoned for borehole instability in intermediate section. This paper encompasses a comprehensive analysis of the mechanism of unstable formations reaction to the loss circulation, resultant stuck pipe mechanisms, unsuccessful attempts to cure losses in this zone, improving fly mixed mud inhibition, impacts of modifications in well design on zonal isolation and finally reaching the safest, time and cost-effective solution.
{"title":"Extend Surface Casing Deeper to Eliminate Borehole Instability in Oil Field Turnkey Project","authors":"S. Ullah, Abdulqawi Al-Fakih, M. Almomen, Robert Famiev, A. S. Alatiyyah, Taimour Al Sharif","doi":"10.2118/194711-MS","DOIUrl":"https://doi.org/10.2118/194711-MS","url":null,"abstract":"\u0000 In one of the largest oil fields in Middle East, the typical well design is to set the conductor just 40 ft below the ground, the surface casing 100 ft inside next competent formation due to shallow total loss zone below the conductor and the intermediate casing in the first competent formation before entering the reservoirs interval. The intermediate section includes a combination of formations that have total losses zones and extremely unstable shales, especially when drilled with total losses.\u0000 In most cases, encountering lost circulation results in formation collapse. The severity of the formation collapse risk in this section ranges from simple tights spots cleared with reaming up and down to stuck pipes, sidetracks and in several cases plug and abandonment of wells. To reduce the likelihood and severity of this risk, there was a need to review the casing seats to isolate unstable formations before entering the intermediate loss zones.\u0000 A detailed study was carried out where diverse options were analyzed, including adding a casing string and changing casing seats of existing casing strings. The study concluded that keeping the same number of casing strings and deepening only the surface casing seat as close as possible to the intermediate loss zone, covering the entire unstable formation but not entering the intermediate loss zone, would be the most efficient solution. Experts supported this change based on the principle that dealing with an unstable formation when it is below the loss zone is easier than when the same formation is above the loss zone.\u0000 The new casing seat choice has been successfully implemented at over 100 wells, with 100% success ending the borehole instability problems. Since then there has been no sidetrack or location plugged and abandoned for borehole instability in intermediate section.\u0000 This paper encompasses a comprehensive analysis of the mechanism of unstable formations reaction to the loss circulation, resultant stuck pipe mechanisms, unsuccessful attempts to cure losses in this zone, improving fly mixed mud inhibition, impacts of modifications in well design on zonal isolation and finally reaching the safest, time and cost-effective solution.","PeriodicalId":11031,"journal":{"name":"Day 4 Thu, March 21, 2019","volume":"82 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87145958","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}
M. Hamad, Manal Bawardi, Reem Noaimi, Vishal Lahoti, M. Anderson
Unconventional plays have characteristic differences in geology, field attributes and well parameters that significantly impact the operating model. They have a higher sensitivity to cost and require high volume and continuous drilling activity to maintain production. This necessitates investing in better technologies and processes that can enhance production by capturing well data, production data and events, enabling better analysis of operational and financial performance. The Digital Production Optimization program is aimed at achieving end-to-end production excellence including forecasting, operations and hydrocarbon accounting. This will drive cost efficiencies by enabling better collaboration, analysis and accuracy. This comprehensive approach at hydrocarbon management is the foundation for Operational Excellence and focuses on the key aspects below. Hydrocarbon Allocation: Model flow networks provide automated and manual Field Data Capture (FDC) and perform allocationsDeferment Management: Capture flow network object downtime calculate deferred volumes and provide capability to classify and facilitate root cause analysesProduction Forecasting: Define a standard forecasting process, and implement data gathering and publishing of forecasting resultsEnterprise Production Reporting: Implement enterprise wide production reporting, including standard reports and ad-hoc reporting capabilityProduction and Revenue Accounting (PRA): Provide an accurate and auditable trail for production, sales volume and revenue accounting even at the well level Digital Production Optimization uses real-time tracking, remote monitoring and predictive analytics to achieve production targets and reduction in deferment volume. Introduction of integrated platforms enables clearer line-of-sight from wellhead production to revenue, improve visibility to assets to drive better cost-efficient operations, and increase assurance for top-line results. A typical business case for digital production optimization has the following value drivers and benefit ranges. * Production increase: up to 3%Deferment reduction: 2-6%O&M cost reduction: 1-2%IT cost reduction: 10-20% The initiative provides decision support by relying on the high fidelity of input data, use of advanced analytics, and rigorous business processes. The key to success here is not only investing in the right equipment for good data, or advanced tools and technologies for better analysis, but also enabling change management. The organization needs to establish critical behaviors like collaboration, data driven decision making and accountability. Saudi Arabia Unconventional Resources has embarked on a journey to enable this Operational Excellence by implementing a comprehensive PRA program. In addition, we are managing change to set up the right processes, organizational structure and governance. This will help us achieve precise allocation of production volumes, validation, diagnosis and correction production d
{"title":"Digital Production Optimization Program","authors":"M. Hamad, Manal Bawardi, Reem Noaimi, Vishal Lahoti, M. Anderson","doi":"10.2118/194857-MS","DOIUrl":"https://doi.org/10.2118/194857-MS","url":null,"abstract":"\u0000 Unconventional plays have characteristic differences in geology, field attributes and well parameters that significantly impact the operating model. They have a higher sensitivity to cost and require high volume and continuous drilling activity to maintain production. This necessitates investing in better technologies and processes that can enhance production by capturing well data, production data and events, enabling better analysis of operational and financial performance.\u0000 The Digital Production Optimization program is aimed at achieving end-to-end production excellence including forecasting, operations and hydrocarbon accounting. This will drive cost efficiencies by enabling better collaboration, analysis and accuracy. This comprehensive approach at hydrocarbon management is the foundation for Operational Excellence and focuses on the key aspects below. Hydrocarbon Allocation: Model flow networks provide automated and manual Field Data Capture (FDC) and perform allocationsDeferment Management: Capture flow network object downtime calculate deferred volumes and provide capability to classify and facilitate root cause analysesProduction Forecasting: Define a standard forecasting process, and implement data gathering and publishing of forecasting resultsEnterprise Production Reporting: Implement enterprise wide production reporting, including standard reports and ad-hoc reporting capabilityProduction and Revenue Accounting (PRA): Provide an accurate and auditable trail for production, sales volume and revenue accounting even at the well level\u0000 Digital Production Optimization uses real-time tracking, remote monitoring and predictive analytics to achieve production targets and reduction in deferment volume. Introduction of integrated platforms enables clearer line-of-sight from wellhead production to revenue, improve visibility to assets to drive better cost-efficient operations, and increase assurance for top-line results. A typical business case for digital production optimization has the following value drivers and benefit ranges. * Production increase: up to 3%Deferment reduction: 2-6%O&M cost reduction: 1-2%IT cost reduction: 10-20%\u0000 The initiative provides decision support by relying on the high fidelity of input data, use of advanced analytics, and rigorous business processes. The key to success here is not only investing in the right equipment for good data, or advanced tools and technologies for better analysis, but also enabling change management. The organization needs to establish critical behaviors like collaboration, data driven decision making and accountability.\u0000 Saudi Arabia Unconventional Resources has embarked on a journey to enable this Operational Excellence by implementing a comprehensive PRA program. In addition, we are managing change to set up the right processes, organizational structure and governance. This will help us achieve precise allocation of production volumes, validation, diagnosis and correction production d","PeriodicalId":11031,"journal":{"name":"Day 4 Thu, March 21, 2019","volume":"18 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73403368","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}
M. Dernaika, Bashar Mansour, O. Aljallad, S. Koronfol
The complexity and diversity of carbonate reservoirs necessitate having a consistent approach in defining rock types. Core data on a rock-type basis are required as input for modelling reservoir performance. The objectives of this paper are to provide detailed understanding of the controlling factors in rock typing and to develop a unique rock-typing approach that can apply to carbonate reservoirs in the Middle East region. More than 1,000 core plugs were studied from seven different carbonate reservoirs. The plugs were carefully selected from 15 wells to represent the primary property variations along the cored intervals. The data set available included laboratory-measured helium porosity, gas permeability, thin-sections, and high-pressure mercury injection capillary pressure (MICP). Plug-scale X-ray computed tomography (CT) imaging was acquired to help ensure the samples were free of induced fractures and other anomalies that can affect the permeability measurements. Rock textures were analyzed in the thin-section photomicrographs and were classified based on their content as grainy, muddy, and mixed. Special attention was given to the diagenesis effects, mainly compaction, cementation, and dissolution. Porosity was defined as interparticle, intercrystalline, moldic, intraparticle, or vuggy. The texture information was plotted in the porosity-permeability (poro-perm) domain and was determined to produce three distinct poro-perm relationships. Each texture provided an unique poro-perm trend. Rock types were defined on the poro-perm trends and showed a strong link to diagenesis and capillary pressure (Pc). For each poro-perm trend, the rock types were distinguished by detailed Dunham textures and different degrees of diagenesis. The detailed textures and diagenesis were correlated reasonably well with the poro-perm data and MICP, hence providing robust rock types. A new rock-typing approach was successfully applied in different carbonate reservoirs. The poro-perm cloud from the different reservoirs was resolved into trends and ranges based on textures and diagenesis. Common controlling factors were observed, which can help produce data analogues along more reservoirs in the region. The texture-diagenesis-based rock types provided more insight into the effects of geology on fluid flow and saturation. Geological textures were derived along the cored intervals and provided upscaling options for permeability and rock types in the reservoirs.
{"title":"Overview of Carbonate Rock Types in the Middle East","authors":"M. Dernaika, Bashar Mansour, O. Aljallad, S. Koronfol","doi":"10.2118/194792-MS","DOIUrl":"https://doi.org/10.2118/194792-MS","url":null,"abstract":"\u0000 The complexity and diversity of carbonate reservoirs necessitate having a consistent approach in defining rock types. Core data on a rock-type basis are required as input for modelling reservoir performance. The objectives of this paper are to provide detailed understanding of the controlling factors in rock typing and to develop a unique rock-typing approach that can apply to carbonate reservoirs in the Middle East region.\u0000 More than 1,000 core plugs were studied from seven different carbonate reservoirs. The plugs were carefully selected from 15 wells to represent the primary property variations along the cored intervals. The data set available included laboratory-measured helium porosity, gas permeability, thin-sections, and high-pressure mercury injection capillary pressure (MICP). Plug-scale X-ray computed tomography (CT) imaging was acquired to help ensure the samples were free of induced fractures and other anomalies that can affect the permeability measurements. Rock textures were analyzed in the thin-section photomicrographs and were classified based on their content as grainy, muddy, and mixed. Special attention was given to the diagenesis effects, mainly compaction, cementation, and dissolution. Porosity was defined as interparticle, intercrystalline, moldic, intraparticle, or vuggy.\u0000 The texture information was plotted in the porosity-permeability (poro-perm) domain and was determined to produce three distinct poro-perm relationships. Each texture provided an unique poro-perm trend. Rock types were defined on the poro-perm trends and showed a strong link to diagenesis and capillary pressure (Pc). For each poro-perm trend, the rock types were distinguished by detailed Dunham textures and different degrees of diagenesis. The detailed textures and diagenesis were correlated reasonably well with the poro-perm data and MICP, hence providing robust rock types.\u0000 A new rock-typing approach was successfully applied in different carbonate reservoirs. The poro-perm cloud from the different reservoirs was resolved into trends and ranges based on textures and diagenesis. Common controlling factors were observed, which can help produce data analogues along more reservoirs in the region. The texture-diagenesis-based rock types provided more insight into the effects of geology on fluid flow and saturation. Geological textures were derived along the cored intervals and provided upscaling options for permeability and rock types in the reservoirs.","PeriodicalId":11031,"journal":{"name":"Day 4 Thu, March 21, 2019","volume":"30 5","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"72621782","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}
Mustafa R. Al-Zaid, Aslan Bulekbay, Abdulaziz Al-Harbi, S. M. Al-Driweesh
Dealing with tight high pressure/high temperature (HPHT) sour gas reservoirs encounters many challenges. One challenge associated with these reservoirs is the development of hard and heavy scale mixture in the production tubing, causing flow and accessibility restrictions. To restore full accessibility, a mechanical de-scaling operations using special milling and cleanout assemblies is the best current solution to this problem, due to the fact that chemical dissolving methods do not deliver the desired results. Another challenge is conventional perforation in some tight wells gives limited penetration, which does not establish the required wellbore reservoir communication. In this case, utilizing the abrasive jetting tool will offer the best solution to overcome the casing string, cement, formation damage achieve optimum penetration which will optimize the stimulation design and enhance the well productivity. In recent years, using coiled tubing (CT) equipped with fiber optics with aforementioned coil tubing intervention operations, have become a common practice in gas wells. Using this system provides the ability to acquire on-job real time data such as pressure, temperature and gamma ray depth correlation. Furthermore, the incorporation of a new rugged fiber optics system into the intervention strategy has enabled increasing operational success rate and results in robust control on the operation parameters, minimizing the risk of gas influx, reducing coil tubing runs and improving decision making process during the operations. This paper describes the challenges in mechanical de-scaling and slot cuttings operations, overview of different applications using CT with fiber optics system, provides a comparison between the rugged and standard fiber optics systems and lessons learned of recent implementation of the rugged CT fiber optic system.
{"title":"Applications of Applying High Rate Coiled Tubing with Fiber Optic System to Meet the Growing Challenges of Coiled Tubing Interventions in Sour Gas Producer Wells","authors":"Mustafa R. Al-Zaid, Aslan Bulekbay, Abdulaziz Al-Harbi, S. M. Al-Driweesh","doi":"10.2118/194724-MS","DOIUrl":"https://doi.org/10.2118/194724-MS","url":null,"abstract":"\u0000 Dealing with tight high pressure/high temperature (HPHT) sour gas reservoirs encounters many challenges. One challenge associated with these reservoirs is the development of hard and heavy scale mixture in the production tubing, causing flow and accessibility restrictions. To restore full accessibility, a mechanical de-scaling operations using special milling and cleanout assemblies is the best current solution to this problem, due to the fact that chemical dissolving methods do not deliver the desired results. Another challenge is conventional perforation in some tight wells gives limited penetration, which does not establish the required wellbore reservoir communication. In this case, utilizing the abrasive jetting tool will offer the best solution to overcome the casing string, cement, formation damage achieve optimum penetration which will optimize the stimulation design and enhance the well productivity.\u0000 In recent years, using coiled tubing (CT) equipped with fiber optics with aforementioned coil tubing intervention operations, have become a common practice in gas wells. Using this system provides the ability to acquire on-job real time data such as pressure, temperature and gamma ray depth correlation. Furthermore, the incorporation of a new rugged fiber optics system into the intervention strategy has enabled increasing operational success rate and results in robust control on the operation parameters, minimizing the risk of gas influx, reducing coil tubing runs and improving decision making process during the operations.\u0000 This paper describes the challenges in mechanical de-scaling and slot cuttings operations, overview of different applications using CT with fiber optics system, provides a comparison between the rugged and standard fiber optics systems and lessons learned of recent implementation of the rugged CT fiber optic system.","PeriodicalId":11031,"journal":{"name":"Day 4 Thu, March 21, 2019","volume":"30 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74367769","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 formation permeability is one of the most important Petrophysical information acquired by low field Nuclear Magnetic Resonance (NMR) data. The absolute permeability of reservoir rocks can be accurately calculated by porosity measured by NMR if permeability is well correlated with porosity [1, 2]. This is true for the rocks with all pores are well connected, such as conventional sandstone reservoir. The correlation between permeability and porosity, however, does not always established well for carbonate reservoir rocks, which are known to have heterogeneous pore-to-pore connectivity. Thus, without accurate pore connectivity information, the permeability derived from NMR data for rocks with poor connection among pores is not quite accurate. The current study proposes a new method to measure an accurate pore-to-pore connectivity from the total volume of a fluid displacement through miscible single phase fluid mixing process. The pore connectivity factor is calculated from the fluid connectivity through different pore systems which can be derived by the volume comparison of NMR invisible D2O replacement with NMR visible H2O in each pore systems. Once the pore connectivity is measured, it is applied to the modified permeability model, such as modified free-fluid model (Timur-Coates model) [3], to calculate accurate permeability. Another benefit of the proposed method is the flexibility of D2O injection condition. Carbonate reservoir rocks with various degrees of connectivity have been studied in the current study. For the verification purpose, the permeabilities calculated by the proposed method have been compared to those measured by other conventional laboratory techniques. The proposed method can also be applied to NMR logging technique for accurate NMR driven permeability derivation which currently accepted as references for reservoirs with complicated connectivity, such as carbonates.
{"title":"Improving the Permeability Derivation from NMR Data for Reservoir Rocks with Complicated Pore Connectivity","authors":"H. Kwak, Jun Gao, A. Harbi","doi":"10.2118/195113-MS","DOIUrl":"https://doi.org/10.2118/195113-MS","url":null,"abstract":"\u0000 The formation permeability is one of the most important Petrophysical information acquired by low field Nuclear Magnetic Resonance (NMR) data. The absolute permeability of reservoir rocks can be accurately calculated by porosity measured by NMR if permeability is well correlated with porosity [1, 2]. This is true for the rocks with all pores are well connected, such as conventional sandstone reservoir. The correlation between permeability and porosity, however, does not always established well for carbonate reservoir rocks, which are known to have heterogeneous pore-to-pore connectivity. Thus, without accurate pore connectivity information, the permeability derived from NMR data for rocks with poor connection among pores is not quite accurate.\u0000 The current study proposes a new method to measure an accurate pore-to-pore connectivity from the total volume of a fluid displacement through miscible single phase fluid mixing process. The pore connectivity factor is calculated from the fluid connectivity through different pore systems which can be derived by the volume comparison of NMR invisible D2O replacement with NMR visible H2O in each pore systems. Once the pore connectivity is measured, it is applied to the modified permeability model, such as modified free-fluid model (Timur-Coates model) [3], to calculate accurate permeability. Another benefit of the proposed method is the flexibility of D2O injection condition.\u0000 Carbonate reservoir rocks with various degrees of connectivity have been studied in the current study. For the verification purpose, the permeabilities calculated by the proposed method have been compared to those measured by other conventional laboratory techniques.\u0000 The proposed method can also be applied to NMR logging technique for accurate NMR driven permeability derivation which currently accepted as references for reservoirs with complicated connectivity, such as carbonates.","PeriodicalId":11031,"journal":{"name":"Day 4 Thu, March 21, 2019","volume":"275 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76517035","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}
Kamlesh Kumar, Zaidi Awang, MohamedOsman. Azzazi., A. Hamdi, B. Hughes, S. Abri
The microporous rock types in Upper Shuaiba are low permeability (~ 1mD) rocks occurring in thin (2-5 m) formations within the extensive Upper Shuaiba carbonate formations in Lekhwair. These microporous rocks constitute a significant volume of hydrocarbon in-place. Unlike the higher quality rudist-rich and grainstone rock types, appraisal pilots in the microporous areas have shown poor performance with waterflood development, which is the preferred development concept in the entire Lekhwair field. Two work streams are active in parallel to identify a technically and commercially feasible development option: Phase 1, technology trials to enable a successful waterflood implementation, and Phase 2, further studies to screen the potential of enhanced oil recovery (EOR) techniques and other light tight oil development. The technology trial work stream, initially considered four initiatives targeting injectivity improvement. To date, trials are complete for abrasive jetting and designer acid stimulation, early results are available for Directional Acid Jetting, and evaluation of Fracture Aligned Sweep Technology (FAST) is ongoing with hydraulic fracturing evaluation accelerated to Phase 1 due to synergies with the FAST evaluation. Trial results to date: Abrasive Jetting: 7 trials complete, limited success in improving injectivity. Designer Acid Stimulation: 1 trial complete, no to limited injectivity improvement Directional Acid Jetting: implemented in 3 wells, injectivity improvement in early injection FAST: trial planning ongoing Hydraulic Fracturing: trial planning ongoing This paper discusses the encouraging results and learnings to date with regard to these new technology trials, and the early screening results for the implementation of gas injection as an alternate recovery mechanism.
{"title":"Strategy Towards Unlocking and Accelerated Development of Low Permeability, Microporous Reservoirs-II","authors":"Kamlesh Kumar, Zaidi Awang, MohamedOsman. Azzazi., A. Hamdi, B. Hughes, S. Abri","doi":"10.2118/194762-MS","DOIUrl":"https://doi.org/10.2118/194762-MS","url":null,"abstract":"\u0000 The microporous rock types in Upper Shuaiba are low permeability (~ 1mD) rocks occurring in thin (2-5 m) formations within the extensive Upper Shuaiba carbonate formations in Lekhwair. These microporous rocks constitute a significant volume of hydrocarbon in-place. Unlike the higher quality rudist-rich and grainstone rock types, appraisal pilots in the microporous areas have shown poor performance with waterflood development, which is the preferred development concept in the entire Lekhwair field. Two work streams are active in parallel to identify a technically and commercially feasible development option: Phase 1, technology trials to enable a successful waterflood implementation, and Phase 2, further studies to screen the potential of enhanced oil recovery (EOR) techniques and other light tight oil development.\u0000 The technology trial work stream, initially considered four initiatives targeting injectivity improvement. To date, trials are complete for abrasive jetting and designer acid stimulation, early results are available for Directional Acid Jetting, and evaluation of Fracture Aligned Sweep Technology (FAST) is ongoing with hydraulic fracturing evaluation accelerated to Phase 1 due to synergies with the FAST evaluation. Trial results to date:\u0000 Abrasive Jetting: 7 trials complete, limited success in improving injectivity. Designer Acid Stimulation: 1 trial complete, no to limited injectivity improvement Directional Acid Jetting: implemented in 3 wells, injectivity improvement in early injection FAST: trial planning ongoing Hydraulic Fracturing: trial planning ongoing\u0000 This paper discusses the encouraging results and learnings to date with regard to these new technology trials, and the early screening results for the implementation of gas injection as an alternate recovery mechanism.","PeriodicalId":11031,"journal":{"name":"Day 4 Thu, March 21, 2019","volume":"109 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75990322","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}
Adeniyi Adams, A. Soliman, Lichuan Deng, Imad Jurdi, Mohamed Salem Al Hosani, Adnan Al Menhali, Jose David Cardona Ardila
The challenge was to achieve more reservoir contact in a cretaceous tight reservoir to improve production and maximize recovery. Multilateral well campaigns were performed to meet these objectives. This case study describes an effective workflow for performing openhole sidetracks in this challenging medium-hard carbonate formation. The workflow maintained reservoir contact and achieved the desired production objectives. Two 6-in. multilateral drain sections were successfully drilled by performing openhole sidetrack using the continuous proportional steering method (CPSM). This method is not new to the industry, but this case study describes the systematic, unique workflow that was designed and followed to ensure a successful sidetrack in this low-porosity, hard formation. The sidetrack implementation started by creating humps at inclinations ranging from 88 to 91 degrees into the formation in the original 6-in. section. These humps were confirmed using near-bit inclination data (4.5 ft from the bit) and were identified as the sites for initiating a sidetrack. This paper discusses the best practices that were key to the successful execution of the project in one run on the first attempt. After the sidetrack, use of appropriate combinations of shallow and deep logging-while-drilling (LWD) measurements in the same bottom hole assembly (BHA) enabled the direct geosteering of the well, exposing more reservoir surface area than planned. A reduction of 10% from the planned well duration was achieved. Two 6-in. laterals, each approximately 4000 ft, were drilled in a single run and 100% reservoir contact was achieved. This experience proved that planning and precise execution could enable drilling of openhole sidetracks, even through hard formations. These sidetracks can then achieve fishbone wells with desired reservoir contact and realize the field development objectives in a technically robust and cost-efficient manner. CPSM does not rely on a pressure drop for steering. Although this proof of concept was performed in a relatively hard formation, similar workflows with appropriate drilling engineering may be applied to less-competent formations as well. The detailed procedure and flowchart created from the experience with the sample well can be adopted for use in similar applications.
{"title":"Continuous Proportional Steering for a Re-Entry Multi-Lateral Well in Cretaceous Reservoir in UAE Saves Rig Days and Achieves Reservoir Contact Objectives in a One-Bit Run","authors":"Adeniyi Adams, A. Soliman, Lichuan Deng, Imad Jurdi, Mohamed Salem Al Hosani, Adnan Al Menhali, Jose David Cardona Ardila","doi":"10.2118/194818-MS","DOIUrl":"https://doi.org/10.2118/194818-MS","url":null,"abstract":"\u0000 The challenge was to achieve more reservoir contact in a cretaceous tight reservoir to improve production and maximize recovery. Multilateral well campaigns were performed to meet these objectives.\u0000 This case study describes an effective workflow for performing openhole sidetracks in this challenging medium-hard carbonate formation. The workflow maintained reservoir contact and achieved the desired production objectives.\u0000 Two 6-in. multilateral drain sections were successfully drilled by performing openhole sidetrack using the continuous proportional steering method (CPSM). This method is not new to the industry, but this case study describes the systematic, unique workflow that was designed and followed to ensure a successful sidetrack in this low-porosity, hard formation.\u0000 The sidetrack implementation started by creating humps at inclinations ranging from 88 to 91 degrees into the formation in the original 6-in. section. These humps were confirmed using near-bit inclination data (4.5 ft from the bit) and were identified as the sites for initiating a sidetrack. This paper discusses the best practices that were key to the successful execution of the project in one run on the first attempt.\u0000 After the sidetrack, use of appropriate combinations of shallow and deep logging-while-drilling (LWD) measurements in the same bottom hole assembly (BHA) enabled the direct geosteering of the well, exposing more reservoir surface area than planned.\u0000 A reduction of 10% from the planned well duration was achieved. Two 6-in. laterals, each approximately 4000 ft, were drilled in a single run and 100% reservoir contact was achieved.\u0000 This experience proved that planning and precise execution could enable drilling of openhole sidetracks, even through hard formations. These sidetracks can then achieve fishbone wells with desired reservoir contact and realize the field development objectives in a technically robust and cost-efficient manner.\u0000 CPSM does not rely on a pressure drop for steering. Although this proof of concept was performed in a relatively hard formation, similar workflows with appropriate drilling engineering may be applied to less-competent formations as well. The detailed procedure and flowchart created from the experience with the sample well can be adopted for use in similar applications.","PeriodicalId":11031,"journal":{"name":"Day 4 Thu, March 21, 2019","volume":"78 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84020519","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}
C. Temizel, C. H. Canbaz, Yildiray Palabiyik, D. Putra, Ahmet Asena, R. Ranjith, K. Jongkittinarukorn
Smart field technologies offer outstanding capabilities that increase the efficiency of the oil and gas fields by means of saving time and energy as far as the technologies employed and workforce concerned given that the technology applied is economic for the field of concern. Despite significant acceptance of smart field concept in the industry, there is still ambiguity not only on the incremental benefits but also the criteria and conditions of applicability technical and economic-wise. This study outlines the past, present and the dynamics of the smart oilfield concept, the techniques and methods it bears and employs, technical challenges in the application while addressing the concerns of the oil and gas industry professionals on the use of such technologies in a comprehensive way. History of smart/intelligent oilfield development, types of technologies used currently in it and those imbibed from other industries are comprehensively reviewed in this paper. In addition, this review takes into account the robustness, applicability and incremental benefits these technologie bring to different types of oilfields under current economic conditions. Real field applications are illustrated with applications in different parts of the world with challenges, advantages and drawbacks discussed and summarized that lead to conclusions on the criteria of application of smart field technologies in an individual field. Intelligent or Smart field concept has proven itself as a promising area and found vast amount of application in oil and gas fields throughout the world. The key in smart oilfield applications is the suitability of an individual case for such technology in terms of technical and economic aspects. This study outlines the key criteria in the success of smart oilfield applications in a given field that will serve for the future decisions as a comprehensive and collective review of all the aspects of the employed techniques and their usability in specific cases. Even though there are publications on certain examples of smart oilfield technologies, a comprehensive review that not only outlines all the key elements in one study but also deducts lessons from the real field applications that will shed light on the utilization of the methods in the future applications has been missing, this study will fill this gap.
{"title":"A Comprehensive Review of Smart/Intelligent Oilfield Technologies and Applications in the Oil and Gas Industry","authors":"C. Temizel, C. H. Canbaz, Yildiray Palabiyik, D. Putra, Ahmet Asena, R. Ranjith, K. Jongkittinarukorn","doi":"10.2118/195095-MS","DOIUrl":"https://doi.org/10.2118/195095-MS","url":null,"abstract":"\u0000 Smart field technologies offer outstanding capabilities that increase the efficiency of the oil and gas fields by means of saving time and energy as far as the technologies employed and workforce concerned given that the technology applied is economic for the field of concern. Despite significant acceptance of smart field concept in the industry, there is still ambiguity not only on the incremental benefits but also the criteria and conditions of applicability technical and economic-wise. This study outlines the past, present and the dynamics of the smart oilfield concept, the techniques and methods it bears and employs, technical challenges in the application while addressing the concerns of the oil and gas industry professionals on the use of such technologies in a comprehensive way.\u0000 History of smart/intelligent oilfield development, types of technologies used currently in it and those imbibed from other industries are comprehensively reviewed in this paper. In addition, this review takes into account the robustness, applicability and incremental benefits these technologie bring to different types of oilfields under current economic conditions. Real field applications are illustrated with applications in different parts of the world with challenges, advantages and drawbacks discussed and summarized that lead to conclusions on the criteria of application of smart field technologies in an individual field.\u0000 Intelligent or Smart field concept has proven itself as a promising area and found vast amount of application in oil and gas fields throughout the world. The key in smart oilfield applications is the suitability of an individual case for such technology in terms of technical and economic aspects. This study outlines the key criteria in the success of smart oilfield applications in a given field that will serve for the future decisions as a comprehensive and collective review of all the aspects of the employed techniques and their usability in specific cases.\u0000 Even though there are publications on certain examples of smart oilfield technologies, a comprehensive review that not only outlines all the key elements in one study but also deducts lessons from the real field applications that will shed light on the utilization of the methods in the future applications has been missing, this study will fill this gap.","PeriodicalId":11031,"journal":{"name":"Day 4 Thu, March 21, 2019","volume":"2 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82562324","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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