South Ordos sandstone reservoir is mainly featured by tiny pore, which mainstream throat radius is around 50nm, high filtration resistance, resulting in low oil productivity and more obvious non-linear seepage characteristics. As of low formation pressure, well production is poor and declines dramatically, therefore primary recovery is hard to sustain effective development for the reservoir. The core problem of tight oil development focuses on the evaluation of tight matrix flowing capability and reservoir producing condition. In the paper, in Ordos typical tight oil basin, by means of microscopic flowing simulation, numerical simulation as well as lab experiments results, single-phase and oil-water two-phrase flowing mechanisms have been analyzed, revealing tight oil single phase percolating resistance and movable oil saturation, providing key evaluation parameters for effective reservoir division. For oil-water two-phase flowing, Jamin effect is so serious that water flooding is hard to displace the oil in micro-pores, accordingly relative permeability and displacement efficiency are calculated. Tight matrix-fracture coupling model recovery mechanism have been analyzed, effective producing radius and mechanism of matrix are defined in the condition of fracturing horizontal wells developing, according to which productivity percentage of Ordos tight oil between fracture and matrix have been determined. On basis of geology evaluation and reservoir engineering analysis, correlation of geological properties-well dynamic characteristics are set up, then influencing factors have been studied to identify tight oil producing conditions on depletion development at different oil price. As different classified fracture developed in the reservoir, water flooding producing condition has been studied, laying the foundation for study of effective development method and technical strategy. Our research indicates that Ordos tight matrix is of low productivity, with movable water saturation increasing, well productivity sharp decline. During production period, production ratio from fracture is only amounted to 6~14% of accumulation oil. Fully excavating the potential of matrix reserves is predominant to achieve effective development of tight oil. Owing to high start-up pressure gradient, as high as 0.1~0.2MPa/m, for water flooding development, well spacing should be reduced to 50m□ to set up pressure response without fracture developing. While in Ordos basin natural fracture is developed, water channeling is so heavy that accumulative oil is lower than depletion method. CO2 start-up pressure gradient is far smaller than that of water flooding with composite EOR mechanisms, expected to be an effective injection medium for tight oil. It is a critical period how so many shut-in wells could be revitalized under low oil price condition. Relying on research results, Ordos tight oil new development method target has been determined, promoting application research a
{"title":"Study of Tight Oil Flowing Mechanism and Reservoir Producing Conditions for South Edge of Ordos Basin","authors":"Xu Ting, Pu Jun, Qin Xuejie, Yi Wei, Song Wenfang","doi":"10.2118/195001-MS","DOIUrl":"https://doi.org/10.2118/195001-MS","url":null,"abstract":"\u0000 South Ordos sandstone reservoir is mainly featured by tiny pore, which mainstream throat radius is around 50nm, high filtration resistance, resulting in low oil productivity and more obvious non-linear seepage characteristics. As of low formation pressure, well production is poor and declines dramatically, therefore primary recovery is hard to sustain effective development for the reservoir. The core problem of tight oil development focuses on the evaluation of tight matrix flowing capability and reservoir producing condition.\u0000 In the paper, in Ordos typical tight oil basin, by means of microscopic flowing simulation, numerical simulation as well as lab experiments results, single-phase and oil-water two-phrase flowing mechanisms have been analyzed, revealing tight oil single phase percolating resistance and movable oil saturation, providing key evaluation parameters for effective reservoir division. For oil-water two-phase flowing, Jamin effect is so serious that water flooding is hard to displace the oil in micro-pores, accordingly relative permeability and displacement efficiency are calculated. Tight matrix-fracture coupling model recovery mechanism have been analyzed, effective producing radius and mechanism of matrix are defined in the condition of fracturing horizontal wells developing, according to which productivity percentage of Ordos tight oil between fracture and matrix have been determined. On basis of geology evaluation and reservoir engineering analysis, correlation of geological properties-well dynamic characteristics are set up, then influencing factors have been studied to identify tight oil producing conditions on depletion development at different oil price. As different classified fracture developed in the reservoir, water flooding producing condition has been studied, laying the foundation for study of effective development method and technical strategy.\u0000 Our research indicates that Ordos tight matrix is of low productivity, with movable water saturation increasing, well productivity sharp decline. During production period, production ratio from fracture is only amounted to 6~14% of accumulation oil. Fully excavating the potential of matrix reserves is predominant to achieve effective development of tight oil. Owing to high start-up pressure gradient, as high as 0.1~0.2MPa/m, for water flooding development, well spacing should be reduced to 50m□ to set up pressure response without fracture developing. While in Ordos basin natural fracture is developed, water channeling is so heavy that accumulative oil is lower than depletion method. CO2 start-up pressure gradient is far smaller than that of water flooding with composite EOR mechanisms, expected to be an effective injection medium for tight oil.\u0000 It is a critical period how so many shut-in wells could be revitalized under low oil price condition. Relying on research results, Ordos tight oil new development method target has been determined, promoting application research a","PeriodicalId":11031,"journal":{"name":"Day 4 Thu, March 21, 2019","volume":"9 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78477723","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}
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}
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}
Dragon Oil operates the Cheleken field in the Caspian Sea offshore Turkmenistan. The production system consists of multiple wellhead and manifold platforms, a complex network of infield carbon steel and flexible flowlines to handle production from HP and LP systems and a 30" × 40 km TL to transport the produced fluids to the CPSF (Central Processing and Storage Facility) located onshore. In addition to the complexities of the flowlines network, the development has a number of unique features that pose challenges to the daily production operation activities such as: -Relatively low reservoir temperatures;-Waxy oil with high WAT (Wax Appearance Temperature) and Pour Point;-Complicated bathymetry of the 30" TL (Trunkline);-Complex reservoirs leading to uncertainty in rates;-Increasing water production;-Increasing sand ingress;-Necessity to commingle water from different sources in the flowlines;-Corrosion, erosion and emulsion occurrence; While management of any of the Flow Assurance issues is well understood on stand-alone basis; there is no definite guidelines to manage them simultaneously through understanding their impact on each other. Obtaining flawless understanding of the nature and extent of each of the impediments issues was a key element for Dragon Oil's team to innovate this approach to minimizing the overall negative impact on production operations. The approach has been developed based on balancing the hydrophobic, hydrophilic and molecular properties of the produced fluids in correlation with the physical criteria of each of the issues to minimize the impact on the others. This paper presents the key elements of a novel approach developed to control the impact of some issues and maintain the deliverability and integrity of the 30" TL. The approach consisted of the following activities:Conducted thorough and rigorous fluids’ analyses;Generated comprehensive operating pressure-temperature envelop during different operational and ambient conditions in the 30" TL;Constructed the occurrence envelops of Flow Assurance issues focusing on wax deposition and severe slugging;Ensured adequacy of slug catching capability at the CPSF and proper procedures to operate;Controlled gas rates to generate severe slugging in the 30" TL;Monitored the performance of the 30" TL (and eventually the system) through close observations to the changes in the key controlling parameters e.g. pressure drop, outcomes of pigging operations and efficiency of separation.
{"title":"From Pore to Process: Novel Flow Assurance Approach to Suppress Severe Production Chemistry Issues by Flow Dynamic Characterization","authors":"Amir T. Alwazzan, M. Dashtebayaz, Mohamed Fiaz","doi":"10.2118/194768-MS","DOIUrl":"https://doi.org/10.2118/194768-MS","url":null,"abstract":"\u0000 Dragon Oil operates the Cheleken field in the Caspian Sea offshore Turkmenistan. The production system consists of multiple wellhead and manifold platforms, a complex network of infield carbon steel and flexible flowlines to handle production from HP and LP systems and a 30\" × 40 km TL to transport the produced fluids to the CPSF (Central Processing and Storage Facility) located onshore. In addition to the complexities of the flowlines network, the development has a number of unique features that pose challenges to the daily production operation activities such as: -Relatively low reservoir temperatures;-Waxy oil with high WAT (Wax Appearance Temperature) and Pour Point;-Complicated bathymetry of the 30\" TL (Trunkline);-Complex reservoirs leading to uncertainty in rates;-Increasing water production;-Increasing sand ingress;-Necessity to commingle water from different sources in the flowlines;-Corrosion, erosion and emulsion occurrence;\u0000 While management of any of the Flow Assurance issues is well understood on stand-alone basis; there is no definite guidelines to manage them simultaneously through understanding their impact on each other. Obtaining flawless understanding of the nature and extent of each of the impediments issues was a key element for Dragon Oil's team to innovate this approach to minimizing the overall negative impact on production operations. The approach has been developed based on balancing the hydrophobic, hydrophilic and molecular properties of the produced fluids in correlation with the physical criteria of each of the issues to minimize the impact on the others.\u0000 This paper presents the key elements of a novel approach developed to control the impact of some issues and maintain the deliverability and integrity of the 30\" TL. The approach consisted of the following activities:Conducted thorough and rigorous fluids’ analyses;Generated comprehensive operating pressure-temperature envelop during different operational and ambient conditions in the 30\" TL;Constructed the occurrence envelops of Flow Assurance issues focusing on wax deposition and severe slugging;Ensured adequacy of slug catching capability at the CPSF and proper procedures to operate;Controlled gas rates to generate severe slugging in the 30\" TL;Monitored the performance of the 30\" TL (and eventually the system) through close observations to the changes in the key controlling parameters e.g. pressure drop, outcomes of pigging operations and efficiency of separation.","PeriodicalId":11031,"journal":{"name":"Day 4 Thu, March 21, 2019","volume":"31 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77264667","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}
Shale has been a major destination for unconventional hydrocarbon resources for its wide stratigraphic coverage as well as high volumetric hydrocarbon potential. Contemporary success in North American shale plays has intrigued operators worldwide in shale exploration. Organic richness has been a key factor to determine the potential of shale as it is proportional to the amount of hydrocarbon likely to be generated and stored in available spaces within the shale. The other important factor in this context is shale brittleness as it indicates how fracable the potential shale is. Attempts are made here by strategically using standard wireline logs in order to evaluate potential of Eocene Vadaparru Shale in Krishna Godavari Basin, India qualitatively and quantitatively. The technique used in this study involves identification of organic lean ‘clean shale’ interval and establishing a ‘clean shale’ relation of resistivity as a function of compressional sonic transit time in the study wells, as both the logs respond comparably to shale and its organic content. Using this relation a proxy ‘clean shale’ resistivity log is generated in shale and compared with measured wireline resistivity. A positive separation between calculated and measured resistivity is then assessed as proportionate shale organic richness, owing to the presence of relatively less dense (corresponding to longer sonic transit time) and more resistive organic content. Shale brittleness is predicted from Young's modulus and Poisson's ratio using compressional, shear and Stoneley wave velocities obtained from sonic measurements, assuming transversely isotropic nature of Vadaparru Shale. The Eocene marine transgressive Vadaparru Shale is a dominant stratigraphy in KG basin as evident from seismics and drilling. Petrophysical analyses in study wells indicated appreciable brittleness within Vadaparru Shale. The organic richness i.e. amount of positive separation between calculated and measured resistivity combined with brittleness quantitatively indicate fair to excellent unconventional potential of Vadaparru Shale. Considerable thickness, Type-II, III kerogen content and geochemical measurements support the study and highlight it as a promising ‘shale reservoir’ destination. In the context of rapidly growing energy demand of India Vadaparru Shale can be considered as serious unconventional player. Overall this study presents quick strategy for shale potential quantification, thus allowing operators to focus spatially in the quest of unconventional hydrocarbon resources.
{"title":"Petrophysical Evaluation of Organic Richness and Brittleness of Shale for Unconventional Hydrocarbon Prospecting: A Case Study on Vadaparru Shale, Krishna Godavari Basin, India","authors":"Arijit Sahu, M. K. Das","doi":"10.2118/194976-MS","DOIUrl":"https://doi.org/10.2118/194976-MS","url":null,"abstract":"\u0000 \u0000 \u0000 Shale has been a major destination for unconventional hydrocarbon resources for its wide stratigraphic coverage as well as high volumetric hydrocarbon potential. Contemporary success in North American shale plays has intrigued operators worldwide in shale exploration. Organic richness has been a key factor to determine the potential of shale as it is proportional to the amount of hydrocarbon likely to be generated and stored in available spaces within the shale. The other important factor in this context is shale brittleness as it indicates how fracable the potential shale is. Attempts are made here by strategically using standard wireline logs in order to evaluate potential of Eocene Vadaparru Shale in Krishna Godavari Basin, India qualitatively and quantitatively.\u0000 \u0000 \u0000 \u0000 The technique used in this study involves identification of organic lean ‘clean shale’ interval and establishing a ‘clean shale’ relation of resistivity as a function of compressional sonic transit time in the study wells, as both the logs respond comparably to shale and its organic content. Using this relation a proxy ‘clean shale’ resistivity log is generated in shale and compared with measured wireline resistivity. A positive separation between calculated and measured resistivity is then assessed as proportionate shale organic richness, owing to the presence of relatively less dense (corresponding to longer sonic transit time) and more resistive organic content. Shale brittleness is predicted from Young's modulus and Poisson's ratio using compressional, shear and Stoneley wave velocities obtained from sonic measurements, assuming transversely isotropic nature of Vadaparru Shale.\u0000 \u0000 \u0000 \u0000 The Eocene marine transgressive Vadaparru Shale is a dominant stratigraphy in KG basin as evident from seismics and drilling. Petrophysical analyses in study wells indicated appreciable brittleness within Vadaparru Shale. The organic richness i.e. amount of positive separation between calculated and measured resistivity combined with brittleness quantitatively indicate fair to excellent unconventional potential of Vadaparru Shale. Considerable thickness, Type-II, III kerogen content and geochemical measurements support the study and highlight it as a promising ‘shale reservoir’ destination. In the context of rapidly growing energy demand of India Vadaparru Shale can be considered as serious unconventional player.\u0000 \u0000 \u0000 \u0000 Overall this study presents quick strategy for shale potential quantification, thus allowing operators to focus spatially in the quest of unconventional hydrocarbon resources.\u0000","PeriodicalId":11031,"journal":{"name":"Day 4 Thu, March 21, 2019","volume":"128 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85560609","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. Grutters, S. Shetty, Winthrop Brown, R. Dunn, Brendan Coadey
There is a growing demand for digital solutions to improve efficiency of oil & gas processing. The ultimate goal is digital platforms that connect multiple information sources, both software and hardware, to make better operational decisions and dramatically improve efficiency. Development of these holistic platforms is still relatively new, although various smaller applications of data digitization and equipment automation do exist. In this paper three field cases will be given to demonstrate the powerful benefits of data digitization and automation. Field Case 1 describes a data management tool that connects field data with SAP and LIMS. The customizable surveillance screens refresh with new laboratory data as soon as they are uploaded in LIMS, and show how water composition trends in relation to corrosion coupons help to optimize costs for corrosion inhibitor. Field Case 2 describes a completely autonomous injection skid to mitigate H2S in a well that requires periodic intervention for paraffin treatment. A scavenger is injected downhole at a dosage rate that is determined by real-time H2S analysers coupled with production flow data, and maintains a zero concentration of H2S at the well head. This novel solution improves personnel safety by enabling work-over crews to work under less hazardous conditions. Field Case 3 describes an automated system for a refinery cooling water system, where a single controller orchestrates five chemical injection pumps based on real-time input from multiple analysers and sensors. From these field cases it can be concluded that digitization and automation tools provide easy, cost- effective and powerful solutions to improve efficiency in oilfield operations. It enables field operators and managers to focus on value adding tasks. When the vast downstream experience of using sophisticated controllers, sensors and analysers is applied to upstream environments efficiency in oil & gas processing facilities can be further improved with lower human intervention.
{"title":"Automation in Upstream Production Chemicals: Learning from Downstream","authors":"M. Grutters, S. Shetty, Winthrop Brown, R. Dunn, Brendan Coadey","doi":"10.2118/195112-MS","DOIUrl":"https://doi.org/10.2118/195112-MS","url":null,"abstract":"\u0000 There is a growing demand for digital solutions to improve efficiency of oil & gas processing. The ultimate goal is digital platforms that connect multiple information sources, both software and hardware, to make better operational decisions and dramatically improve efficiency. Development of these holistic platforms is still relatively new, although various smaller applications of data digitization and equipment automation do exist. In this paper three field cases will be given to demonstrate the powerful benefits of data digitization and automation. Field Case 1 describes a data management tool that connects field data with SAP and LIMS. The customizable surveillance screens refresh with new laboratory data as soon as they are uploaded in LIMS, and show how water composition trends in relation to corrosion coupons help to optimize costs for corrosion inhibitor. Field Case 2 describes a completely autonomous injection skid to mitigate H2S in a well that requires periodic intervention for paraffin treatment. A scavenger is injected downhole at a dosage rate that is determined by real-time H2S analysers coupled with production flow data, and maintains a zero concentration of H2S at the well head. This novel solution improves personnel safety by enabling work-over crews to work under less hazardous conditions. Field Case 3 describes an automated system for a refinery cooling water system, where a single controller orchestrates five chemical injection pumps based on real-time input from multiple analysers and sensors. From these field cases it can be concluded that digitization and automation tools provide easy, cost- effective and powerful solutions to improve efficiency in oilfield operations. It enables field operators and managers to focus on value adding tasks. When the vast downstream experience of using sophisticated controllers, sensors and analysers is applied to upstream environments efficiency in oil & gas processing facilities can be further improved with lower human intervention.","PeriodicalId":11031,"journal":{"name":"Day 4 Thu, March 21, 2019","volume":"56 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88620469","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 study offers a thorough assessment of two contract awarding strategies; Lump Sum Turn Key (LSTK) Versus Lump Sum Procure and Build (LSPB) conducted specifically for C1(≤100 Million USD) budget projects. The study objective is to access and compare the Pros and Cons of each type of awarding strategies over four specific aspects; (1) project budget size, (2) awarding period length, (3) procurement cycle, and (4) level of engineering detail design scope of work. The effect of the project driver and stakeholders’ requirement on each of the 4 aspects is considered and analyzed. Also, the effect of a fifth aspect (brown field Vs green field) is evaluated and introduced in our study as "control". This assessment is conducted as a case study for an ongoing C1 budget project. The evaluation compares realistic time frames utilizing PERT and GANTT charts. The time frames are extracted from processes mandated by "Company" Engineering procedures" SAEP". The two awarding strategies are analyzed using "5 WHYs" technique and fish-bone analysis method for this specific case study. The project activities critical path was driven and analyzed. Level 3 schedules are built using Primavera Software. Data for all 4 aspects were obtained from the company Bench Mark projects and recommended procedures. It was observed that each of aspect number (1), (2), and (3) on its own cannot be a decisive measure to choose a specific contracting strategy for this specific low budget category, C1 projects. You need the stakeholders requirement that is translated into project initiating driver as a core input to steer the decision for selecting the contract awarding strategy. Hence, the assessment of selecting the awarding strategy for C1 projects would show different results if the project is "Cost Driven" Versus if it is to "Schedule Driven′′. For instance, if the project is initiated to maintain business then, the stakeholders would be expediting the execution and completion of the project. Thus, Project Management Team (PMT) will be on great pressure to visit all time saving avenues starting with the contracting strategy. On the other hand, if the project is cost driven then, the awarding strategy that results in lower expenditures will be selected. However, the study concluded that the level of complexity of the engineering detail design scope for a C1 project should be a decisive factor on its own for the choice of the contract awarding strategy. The reason for this conclusion is to avoid wasting valuable resources that could be exhausted in rework. This assessment was conducted using top notch project management softwares merged with lean management methodologies. The author is a strong advocate of introducing lean thinking in project management of Oil and Gas construction project. In his current job with "The Company", he is implementing Lean thinking and process improvement techniques in all project management responsibilities and has published a paper with MOES 2017
{"title":"Assessment of Two Contract Awarding Strategies; Lump Sum Turn Key LSTK and Lump Sum Procure and Build LSPB for Low Budget Oil and Gas Construction Projects C1; Less than 100 Million USD","authors":"M. Ibrahim","doi":"10.2118/195033-MS","DOIUrl":"https://doi.org/10.2118/195033-MS","url":null,"abstract":"\u0000 This study offers a thorough assessment of two contract awarding strategies; Lump Sum Turn Key (LSTK) Versus Lump Sum Procure and Build (LSPB) conducted specifically for C1(≤100 Million USD) budget projects. The study objective is to access and compare the Pros and Cons of each type of awarding strategies over four specific aspects; (1) project budget size, (2) awarding period length, (3) procurement cycle, and (4) level of engineering detail design scope of work. The effect of the project driver and stakeholders’ requirement on each of the 4 aspects is considered and analyzed. Also, the effect of a fifth aspect (brown field Vs green field) is evaluated and introduced in our study as \"control\". This assessment is conducted as a case study for an ongoing C1 budget project. The evaluation compares realistic time frames utilizing PERT and GANTT charts. The time frames are extracted from processes mandated by \"Company\" Engineering procedures\" SAEP\". The two awarding strategies are analyzed using \"5 WHYs\" technique and fish-bone analysis method for this specific case study. The project activities critical path was driven and analyzed. Level 3 schedules are built using Primavera Software.\u0000 Data for all 4 aspects were obtained from the company Bench Mark projects and recommended procedures. It was observed that each of aspect number (1), (2), and (3) on its own cannot be a decisive measure to choose a specific contracting strategy for this specific low budget category, C1 projects. You need the stakeholders requirement that is translated into project initiating driver as a core input to steer the decision for selecting the contract awarding strategy. Hence, the assessment of selecting the awarding strategy for C1 projects would show different results if the project is \"Cost Driven\" Versus if it is to \"Schedule Driven′′. For instance, if the project is initiated to maintain business then, the stakeholders would be expediting the execution and completion of the project. Thus, Project Management Team (PMT) will be on great pressure to visit all time saving avenues starting with the contracting strategy. On the other hand, if the project is cost driven then, the awarding strategy that results in lower expenditures will be selected. However, the study concluded that the level of complexity of the engineering detail design scope for a C1 project should be a decisive factor on its own for the choice of the contract awarding strategy. The reason for this conclusion is to avoid wasting valuable resources that could be exhausted in rework. This assessment was conducted using top notch project management softwares merged with lean management methodologies. The author is a strong advocate of introducing lean thinking in project management of Oil and Gas construction project. In his current job with \"The Company\", he is implementing Lean thinking and process improvement techniques in all project management responsibilities and has published a paper with MOES 2017 ","PeriodicalId":11031,"journal":{"name":"Day 4 Thu, March 21, 2019","volume":"72 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88794053","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. Greenhalgh, A. Al-Lehyani, C. Schmelzbach, D. Sollberger
The bearing and elevation (azimuth and inclination) of a seismic event can be estimated directly from measurements at a single triaxial station. There are instances in which the angular resolution secured by triaxial polarization analysis is better than that obtained by beamforming with an extended scalar array. In these situations, one depends totally on understanding the inter-relationships between the triaxial records that make up a seismic wavetrain. There are many approaches to seismic direction finding (SDF). Monte-Carlo techniques of triaxial seismic direction finding seek to maximise signal power by examining the seismic wavefield in many rotated co-ordinate frames. There are variants on this approach, which entail null seeking in an inverse space. Instead of searching all possible directions for the one which best fits the polarization model of a single arrival, it is possible to carry out an eigen-decomposition of the (complex or real) covariance matrix formed from the three-component data. The eigenvector corresponding to the principal eigenvalue yields the polarization direction automatically, with significant savings in computational effort. Numerical experiments undertaken for different levels of random noise superimposed on a pure mode signal show that there are no significant advantages in using the Monte-Carlo techniques over eigendecompsoition. Confidence measures of event detection may be obtained by examining eigenvalue ratios when using the eigendecompsoition method. A time-domain formulation (covariance or coherency matrix) is preferable to a frequency-domain formulation (cross-spectral matrix) when there are multiple transient events present. The analysis window should be as long as possible (at least half the dominant period of the signal) without causing separate events to interfere. In practise, the direction-of-arrival estimates deteriorate with increasing levels of random noise, and are generally unacceptable for a SNR of less than 1. Special care is needed to avoid direction errors associated with systematic noise, such as sensor gain misalignment between channels, coupling variations between receiver components, velocity inhomogeneity and anisotropy, the free-surface effect, and multiple event interference.
{"title":"Single Station Triaxial Seismic Event Detection, Direction Finding and Polarization Analysis","authors":"S. Greenhalgh, A. Al-Lehyani, C. Schmelzbach, D. Sollberger","doi":"10.2118/194941-MS","DOIUrl":"https://doi.org/10.2118/194941-MS","url":null,"abstract":"\u0000 The bearing and elevation (azimuth and inclination) of a seismic event can be estimated directly from measurements at a single triaxial station. There are instances in which the angular resolution secured by triaxial polarization analysis is better than that obtained by beamforming with an extended scalar array. In these situations, one depends totally on understanding the inter-relationships between the triaxial records that make up a seismic wavetrain. There are many approaches to seismic direction finding (SDF). Monte-Carlo techniques of triaxial seismic direction finding seek to maximise signal power by examining the seismic wavefield in many rotated co-ordinate frames. There are variants on this approach, which entail null seeking in an inverse space. Instead of searching all possible directions for the one which best fits the polarization model of a single arrival, it is possible to carry out an eigen-decomposition of the (complex or real) covariance matrix formed from the three-component data. The eigenvector corresponding to the principal eigenvalue yields the polarization direction automatically, with significant savings in computational effort.\u0000 Numerical experiments undertaken for different levels of random noise superimposed on a pure mode signal show that there are no significant advantages in using the Monte-Carlo techniques over eigendecompsoition. Confidence measures of event detection may be obtained by examining eigenvalue ratios when using the eigendecompsoition method. A time-domain formulation (covariance or coherency matrix) is preferable to a frequency-domain formulation (cross-spectral matrix) when there are multiple transient events present. The analysis window should be as long as possible (at least half the dominant period of the signal) without causing separate events to interfere.\u0000 In practise, the direction-of-arrival estimates deteriorate with increasing levels of random noise, and are generally unacceptable for a SNR of less than 1. Special care is needed to avoid direction errors associated with systematic noise, such as sensor gain misalignment between channels, coupling variations between receiver components, velocity inhomogeneity and anisotropy, the free-surface effect, and multiple event interference.","PeriodicalId":11031,"journal":{"name":"Day 4 Thu, March 21, 2019","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82837899","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
A. Amer, A. Sajer, T. Al-Adwani, Hanan Salem, R. Abu-Taleb, Ali Abu-Guneej, A. Yateem, Vishnu Chilumuri, P. Goyal, S. Devkar
Producing unconventional reservoirs characterized by low porosities and permeabilities during early stages of exploration and field appraisal can be challenging, especially in high temperature and high pressure (HPHT) downhole conditions. In such reservoirs, the natural fracture network can play a significant role in flowing hydrocarbons, increasing the importance of encountering such network by the boreholes. Consequently, the challenge would be to plan wells through these corridors, which is not always easy. To add to the challenge, well design restrictions dictate, the drilling of only vertical and in minor cases deviated wells. This can reduce the possibility of drilling through sub-vertical fracture sets significantly, and once seismic resolution is considered, it may seem that all odds are agents encountering a fracture network. This article addresses a case where a vertical well is drilled, in the above-mentioned reservoir setting, and missed the natural fracture system. The correct mitigation can make a difference between plugging and abandoning the well or putting it on production. The technique utilized is based on a borehole acoustic reflection survey (BARS) acquired over a vertical well to give a detailed insight on the fracture network 120 ft away from the borehole. Integrating this technique with core and high-resolution borehole image logs rendered an excellent match, increasing the confidence level in the acoustically predicted fracture corridors. Based on these findings new perforation intervals and hydraulic stimulation are proposed to optimize well performance. Such application can reverse the well decommissioning process, opening new opportunities for the rejuvenation of older wells.
{"title":"The Application of Downhole Seismic Imaging in Identifying Natural Fracture Systems; An Integrated Approach Utilizing Core and Borehole Image Data","authors":"A. Amer, A. Sajer, T. Al-Adwani, Hanan Salem, R. Abu-Taleb, Ali Abu-Guneej, A. Yateem, Vishnu Chilumuri, P. Goyal, S. Devkar","doi":"10.2118/194903-MS","DOIUrl":"https://doi.org/10.2118/194903-MS","url":null,"abstract":"\u0000 Producing unconventional reservoirs characterized by low porosities and permeabilities during early stages of exploration and field appraisal can be challenging, especially in high temperature and high pressure (HPHT) downhole conditions. In such reservoirs, the natural fracture network can play a significant role in flowing hydrocarbons, increasing the importance of encountering such network by the boreholes.\u0000 Consequently, the challenge would be to plan wells through these corridors, which is not always easy. To add to the challenge, well design restrictions dictate, the drilling of only vertical and in minor cases deviated wells. This can reduce the possibility of drilling through sub-vertical fracture sets significantly, and once seismic resolution is considered, it may seem that all odds are agents encountering a fracture network.\u0000 This article addresses a case where a vertical well is drilled, in the above-mentioned reservoir setting, and missed the natural fracture system. The correct mitigation can make a difference between plugging and abandoning the well or putting it on production.\u0000 The technique utilized is based on a borehole acoustic reflection survey (BARS) acquired over a vertical well to give a detailed insight on the fracture network 120 ft away from the borehole. Integrating this technique with core and high-resolution borehole image logs rendered an excellent match, increasing the confidence level in the acoustically predicted fracture corridors.\u0000 Based on these findings new perforation intervals and hydraulic stimulation are proposed to optimize well performance. Such application can reverse the well decommissioning process, opening new opportunities for the rejuvenation of older wells.","PeriodicalId":11031,"journal":{"name":"Day 4 Thu, March 21, 2019","volume":"52 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90824647","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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