Kuwait Oil Company (KOC) has commissioned a study to determine the potential contribution that Carbon Capture and Storage alone (CCS), Carbon Capture and Storage with Enhanced Oil Recovery (CCS-EOR) or other identified measures could make to reducing Kuwait's / KOC's Greenhouse Gas (GHG) emissions, by implementation of recommendations. This study was examined various methods to reduce GHG emissions, including CCS, and will provide a strategy for the implementation of various GHG emission reduction technologies for KOC of international and national requirements to address the global challenge of climate change, with particular focus on the Middle East and the Oil and Gas industry. A cost effective GHG emission reduction target for KOC is proposed to limit GHG emissions as Business as Usual in 2030. Achieving this target requires implementing the Prioritized GHG Emissions Reduction Plan with specific Key Performance Measures (KPMs) for KOC. This Plan is based on a package of GHG emission reduction measures that would be cost neutral to KOC. Adopting a similar approach across the whole of Kuwait is expected to reduce emissions by 2030 projections. CCS and CCS-EOR would accrue costs but have the potential to make the greatest contribution to reducing GHG emissions. This Study recommends CCS and CCS-EOR are suitable for longer-term consideration. Furthermore, the top management KPMs has been identified that will help the management to monitor and control the GHGs emissions to address the global challenge of climate change.
{"title":"Carbon Capture & Storage Management for Kuwait Oil Company, Kuwait","authors":"Z. Hussain, Fatima Owayed, P. Rao","doi":"10.2118/198079-ms","DOIUrl":"https://doi.org/10.2118/198079-ms","url":null,"abstract":"\u0000 Kuwait Oil Company (KOC) has commissioned a study to determine the potential contribution that Carbon Capture and Storage alone (CCS), Carbon Capture and Storage with Enhanced Oil Recovery (CCS-EOR) or other identified measures could make to reducing Kuwait's / KOC's Greenhouse Gas (GHG) emissions, by implementation of recommendations. This study was examined various methods to reduce GHG emissions, including CCS, and will provide a strategy for the implementation of various GHG emission reduction technologies for KOC of international and national requirements to address the global challenge of climate change, with particular focus on the Middle East and the Oil and Gas industry.\u0000 A cost effective GHG emission reduction target for KOC is proposed to limit GHG emissions as Business as Usual in 2030. Achieving this target requires implementing the Prioritized GHG Emissions Reduction Plan with specific Key Performance Measures (KPMs) for KOC. This Plan is based on a package of GHG emission reduction measures that would be cost neutral to KOC. Adopting a similar approach across the whole of Kuwait is expected to reduce emissions by 2030 projections. CCS and CCS-EOR would accrue costs but have the potential to make the greatest contribution to reducing GHG emissions. This Study recommends CCS and CCS-EOR are suitable for longer-term consideration. Furthermore, the top management KPMs has been identified that will help the management to monitor and control the GHGs emissions to address the global challenge of climate change.","PeriodicalId":282370,"journal":{"name":"Day 2 Mon, October 14, 2019","volume":"6 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129759454","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}
David Nelson Jesudian, J. Coronado, Nour Esam Al-Abboud
Mauddud Formation is a major oil-producing reservoir in Raudhatain Field of North Kuwait. The Mauddud Formation is an early Albian in age and it was generated an environment of the shallow-water carbonate and consists of Grainstones, Wackestones and Mudstones deposited in ramp settings. In Raudhatain field (RAMA) is undertaking massive development efforts with planned enhancement in Oil production. Reservoir description and distribution of rock properties in 3D space are challenging due to inherent reservoir heterogeneity, in this case primarily driven by depositional and diagenetic patterns. KOC North Kuwait Reservoir Studies Team (NK RST) has been challenged to increase the production from several key NK oil fields. To achieve this goal, KOC has partnered with Schlumberger to rebuild integrated model with Petrophysics, Geophysics, and Geology and Reservoir data of the Mauddud Reservoir. The original model was required to minimize challenges in new infill locations, increase Oil recovery factor and detect water breakthrough to minimize water production. One of the key issues in creating RAMA reservoir model is integration of all available data in identifying the horizontal permeability, reservoir heterogeneity and identification of thief zones. A fine Geological grid model with 35M cells, 10 Geological horizons has been built to characterize the Mauddud reservoirs of the RAMA field including the permeability from PLT logs combined with petrophysical and lithological / facies data to add more understanding of the distribution of reservoir properties. Log response group methodology and the undeveloped area in the Saddle (structurally low area) has been modelled for the first time in Raudhatain NK Field. This combined study utilizes the available data and cutting-edge technology using Geo2Flow which resulted in fluid compartmentalization and free water level identification. STOOIP has been upgraded and unlocking potential in new segments of the developed field. The original model was built based on vertical/Deviation wells (345) which lead to discrepancies in the structural interpretation. The new update has been carried out including all horizontal wells to minimize the uncertainty in the structure framework.
{"title":"Integrated High Resolution 3D Model Update in Challenging Mauddud Carbonates, Raudhatain Field, North Kuwait","authors":"David Nelson Jesudian, J. Coronado, Nour Esam Al-Abboud","doi":"10.2118/197988-ms","DOIUrl":"https://doi.org/10.2118/197988-ms","url":null,"abstract":"\u0000 Mauddud Formation is a major oil-producing reservoir in Raudhatain Field of North Kuwait. The Mauddud Formation is an early Albian in age and it was generated an environment of the shallow-water carbonate and consists of Grainstones, Wackestones and Mudstones deposited in ramp settings. In Raudhatain field (RAMA) is undertaking massive development efforts with planned enhancement in Oil production. Reservoir description and distribution of rock properties in 3D space are challenging due to inherent reservoir heterogeneity, in this case primarily driven by depositional and diagenetic patterns.\u0000 KOC North Kuwait Reservoir Studies Team (NK RST) has been challenged to increase the production from several key NK oil fields. To achieve this goal, KOC has partnered with Schlumberger to rebuild integrated model with Petrophysics, Geophysics, and Geology and Reservoir data of the Mauddud Reservoir. The original model was required to minimize challenges in new infill locations, increase Oil recovery factor and detect water breakthrough to minimize water production. One of the key issues in creating RAMA reservoir model is integration of all available data in identifying the horizontal permeability, reservoir heterogeneity and identification of thief zones.\u0000 A fine Geological grid model with 35M cells, 10 Geological horizons has been built to characterize the Mauddud reservoirs of the RAMA field including the permeability from PLT logs combined with petrophysical and lithological / facies data to add more understanding of the distribution of reservoir properties. Log response group methodology and the undeveloped area in the Saddle (structurally low area) has been modelled for the first time in Raudhatain NK Field. This combined study utilizes the available data and cutting-edge technology using Geo2Flow which resulted in fluid compartmentalization and free water level identification. STOOIP has been upgraded and unlocking potential in new segments of the developed field. The original model was built based on vertical/Deviation wells (345) which lead to discrepancies in the structural interpretation. The new update has been carried out including all horizontal wells to minimize the uncertainty in the structure framework.","PeriodicalId":282370,"journal":{"name":"Day 2 Mon, October 14, 2019","volume":"38 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125426388","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}
Xuan Du, Haijiang Zheng, Xiaochun Wang, X. Hua, Wenlong Guan, Fang Zhao, Jiacheng Xu
Heavy oil reservoirs are generally unconsolidated and easy to produce sand during production1. In the late stage of Cyclic Steam Stimulation (CSS), high temperature steam and hot water destroy clay minerals, further aggravate sand production problems, resulting in sand jam, sand burial, pump jam and casing damage, and frequent operations seriously affect the effective production of oil wells. PetroChina has been carrying out steam stimulation for more than 40 years, and has formed a series of sand control technologies in the field of heavy oil thermal recovery. This paper introduces several sand control techniques used in Liaohe and Xinjiang Oilfield and their successful cases. Liaohe and Xinjiang Oilfield is rich in heavy oil resources. The oil types include ordinary heavy oil, extra heavy oil and super heavy oil2. In Liaohe Oilfield, they have medium and deep heavy oil with a depth of 600-900m and super deep heavy oil with a depth of 1300-1700m. As the main development method, CSS has entered the late stage of production, more than 9 cycles, and encountered various sanding problems during the production. By using mechanical sand control and chemical sand control measures, the sand path was controlled, and an artificial wellbore was formed in the near-wellbore zone to control the fine silt. Through the discussion in this paper, we can provide a variety of solutions for sanding problems encountered in heavy oil steam handling.
{"title":"Case Study: Sand Control Technology During CSS in Liaohe and Xinjiang Heavy Oil Reservoirs","authors":"Xuan Du, Haijiang Zheng, Xiaochun Wang, X. Hua, Wenlong Guan, Fang Zhao, Jiacheng Xu","doi":"10.2118/197990-ms","DOIUrl":"https://doi.org/10.2118/197990-ms","url":null,"abstract":"\u0000 Heavy oil reservoirs are generally unconsolidated and easy to produce sand during production1. In the late stage of Cyclic Steam Stimulation (CSS), high temperature steam and hot water destroy clay minerals, further aggravate sand production problems, resulting in sand jam, sand burial, pump jam and casing damage, and frequent operations seriously affect the effective production of oil wells. PetroChina has been carrying out steam stimulation for more than 40 years, and has formed a series of sand control technologies in the field of heavy oil thermal recovery. This paper introduces several sand control techniques used in Liaohe and Xinjiang Oilfield and their successful cases. Liaohe and Xinjiang Oilfield is rich in heavy oil resources. The oil types include ordinary heavy oil, extra heavy oil and super heavy oil2. In Liaohe Oilfield, they have medium and deep heavy oil with a depth of 600-900m and super deep heavy oil with a depth of 1300-1700m. As the main development method, CSS has entered the late stage of production, more than 9 cycles, and encountered various sanding problems during the production. By using mechanical sand control and chemical sand control measures, the sand path was controlled, and an artificial wellbore was formed in the near-wellbore zone to control the fine silt. Through the discussion in this paper, we can provide a variety of solutions for sanding problems encountered in heavy oil steam handling.","PeriodicalId":282370,"journal":{"name":"Day 2 Mon, October 14, 2019","volume":"116 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"117232198","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}
Mazharuddin Shaikh, Majed Al-Mutairi, Anwar Al-Wehaib, S. Al-Enezi
Several major incidents that involved newly commissioned projects with a range of inherent weaknesses bear testimony to the need for building process safety systematically into future engineering projects. The proper integration of hazard and risk studies into a project is key to achieving full potential for safety. One of the main objectives of successfully integrating process safety into a project is to reduce this residual safety risk. This paper describes the best practice developed by Kuwait Oil Company for integrating process safety activities, especially performing PHA studies through out the life cycle of process related facility projects. This paper outlines types of projects at KOC, phases of projects, brief on project requirement at each phase, details on PHA, PHSER and PSSR reviews at each stage of process to adequately assess & manage the risk. The failure to integrate all of these means that processes and project may not achieve their full safe and efficient performance.
{"title":"Do the Right Thing at Right Time KOC Way of Integrating Process Safety into Process Related Facility Projects","authors":"Mazharuddin Shaikh, Majed Al-Mutairi, Anwar Al-Wehaib, S. Al-Enezi","doi":"10.2118/198135-ms","DOIUrl":"https://doi.org/10.2118/198135-ms","url":null,"abstract":"\u0000 Several major incidents that involved newly commissioned projects with a range of inherent weaknesses bear testimony to the need for building process safety systematically into future engineering projects. The proper integration of hazard and risk studies into a project is key to achieving full potential for safety. One of the main objectives of successfully integrating process safety into a project is to reduce this residual safety risk. This paper describes the best practice developed by Kuwait Oil Company for integrating process safety activities, especially performing PHA studies through out the life cycle of process related facility projects. This paper outlines types of projects at KOC, phases of projects, brief on project requirement at each phase, details on PHA, PHSER and PSSR reviews at each stage of process to adequately assess & manage the risk. The failure to integrate all of these means that processes and project may not achieve their full safe and efficient performance.","PeriodicalId":282370,"journal":{"name":"Day 2 Mon, October 14, 2019","volume":"943 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116215977","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}
Mahmoud FawzyFahmy, D. SinghaRay, Mohamed Zekraoui, M. Ghioca, Riyad Qutainah
Middle Marrat resrervoir of Jurrasic age is a tight carbonate reservoir with vertical and horizontal heterogeneous properities. The well placement over deep elonogted anticline with steep dips, geosteering and lowering of production liner are challenging, therefore the field is being developed using horizontal wells cutting across multiple reservoir layers to maximize reservoir contact and driange The low clay content in Marrat reservoirs gives low gamma ray counts, which makes the identification of reservoir layers identification difficult. In addition, the high-resistivity responses from hydrocarbon-bearing pay-zones and from the tight layers make the identification of the reservoir sweet spots difficult as well. Slim-hole magnetic resonance (NMR) logging was deployed in wash-down mode for identifying reservoir sweet-spots as a lithology-independent porosity and formation fluid characterization tool. Magnetic resonance was acquired with dual wait time enabled T2 polarization to differentiate between moveable water and hydrocarbons. After acquisition, the standard deliverables were porosity, the effective porosity ratio, and the permeability index to evaluate the rock qualities. Porosity was divided into clay-bound water (CBW), bulk-volume irreducible (BVI) and bulk-volume moveable (BVM). Rock quality was interpreted and classified based on efftective porosity and permeability index ratios. The ratio where a steeper gradient was interpreted as high flow zones, a gentle gradient as low flow zones, and a flat gradient was considered as tight baffle zones. Based on the MR flow units and fluid types (CBW, BVI and BVM), the drilled interval was classified into six compartments of high flow, one compartment of low flow, and five tight baffle zones. Accordingly, the perforation plan was optimized to fit the high flow units only. Comparing to the conventional log analysis, NMR excluded approximately 1000 ft of non-productive reservoirs, leading to a significant cost savings (250,000 USD) in perforationand production optimization. The well was drilled with a distance-to-bed boundary tool; however, enormous potential exists to use this slim MR tool as a non-radioactive sourceless solution for geosteering through reservoir sweet spots while delivering wells that are more productive safely.
{"title":"Tight Carbonate Reservoir Characterization and Complition Optimization Using Magnetic Resonance in Horizontal Well, Umm-Gudair Field, West Kuwait","authors":"Mahmoud FawzyFahmy, D. SinghaRay, Mohamed Zekraoui, M. Ghioca, Riyad Qutainah","doi":"10.2118/198110-ms","DOIUrl":"https://doi.org/10.2118/198110-ms","url":null,"abstract":"\u0000 Middle Marrat resrervoir of Jurrasic age is a tight carbonate reservoir with vertical and horizontal heterogeneous properities. The well placement over deep elonogted anticline with steep dips, geosteering and lowering of production liner are challenging, therefore the field is being developed using horizontal wells cutting across multiple reservoir layers to maximize reservoir contact and driange\u0000 The low clay content in Marrat reservoirs gives low gamma ray counts, which makes the identification of reservoir layers identification difficult. In addition, the high-resistivity responses from hydrocarbon-bearing pay-zones and from the tight layers make the identification of the reservoir sweet spots difficult as well. Slim-hole magnetic resonance (NMR) logging was deployed in wash-down mode for identifying reservoir sweet-spots as a lithology-independent porosity and formation fluid characterization tool.\u0000 Magnetic resonance was acquired with dual wait time enabled T2 polarization to differentiate between moveable water and hydrocarbons. After acquisition, the standard deliverables were porosity, the effective porosity ratio, and the permeability index to evaluate the rock qualities. Porosity was divided into clay-bound water (CBW), bulk-volume irreducible (BVI) and bulk-volume moveable (BVM). Rock quality was interpreted and classified based on efftective porosity and permeability index ratios. The ratio where a steeper gradient was interpreted as high flow zones, a gentle gradient as low flow zones, and a flat gradient was considered as tight baffle zones.\u0000 Based on the MR flow units and fluid types (CBW, BVI and BVM), the drilled interval was classified into six compartments of high flow, one compartment of low flow, and five tight baffle zones. Accordingly, the perforation plan was optimized to fit the high flow units only. Comparing to the conventional log analysis, NMR excluded approximately 1000 ft of non-productive reservoirs, leading to a significant cost savings (250,000 USD) in perforationand production optimization.\u0000 The well was drilled with a distance-to-bed boundary tool; however, enormous potential exists to use this slim MR tool as a non-radioactive sourceless solution for geosteering through reservoir sweet spots while delivering wells that are more productive safely.","PeriodicalId":282370,"journal":{"name":"Day 2 Mon, October 14, 2019","volume":"11 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122411825","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. T. Al-Murayri, H. Al-Mayyan, Narjes Al-Mahmeed, A. Muthuswamy, G. Shahin, S. Shukla
This paper discusses static and dynamic adsorption experiments to evaluate surfactant and alkali consumption as well as polymer injectivity to guide well perforation design for an Alkaline Surfactant Polymer (ASP) pilot in a giant clastic reservoir in Kuwait. Alkali and surfactant consumption in the reservoir and polymer mechanical degradation near the wellbore have a significant impact on the effectiveness of the injected ASP slug to recover additional oil from the reservoir post water flooding. Aqueous solutions consisting of alkali, surfactant and co-solvent with and without hydrolyzed polyacrylamide polymer were injected into outcrop (Bentheimer) and cleaned reservoir cores at a reservoir temperature of 90°C. The concentration of surfactant and alkali in the effluent stream was measured using potentiometric titration and the retardation of the chemical waves in comparison to the salinity tracer wave was used to estimate chemical adsorption. For the injectivity tests, ASP and polymer drive solutions were injected at various rates into cleaned reservoir core to determine threshold onset rates for screen factor and apparent viscosity loss at room temperature and at 40°C. This laboratory study shows that surfactant adsorption can be higher when the experiments are conducted using reservoir core at the reservoir temperature of 90°C compared to literature reported adsorption values for internal olefin sulfonates (IOS) on Berea rock in the absence of alkali and polymer at room temperature. Both the static and dynamic adsorption experiments revealed that surfactant adsorption and alkali consumption was reduced in the presence of polymer. This is likely due to a competition between surfactant and polymer molecules for the adsorption sites on the rock surface. The polymer injectivity tests showed that screen factor declined above a Darcy velocity of 83 ft/day and apparent viscosity peaked at a Darcy velocity of 166 ft/day. Based on these results, it was recommended that well perforations for injection wells be designed such that flow rate does not exceed 100 - 150 ft/day to preserve the benefits of mobility control through ASP and polymer injection.
{"title":"Alkali-Surfactant Adsorption and Polymer Injectivity Measurements Using Reservoir Core from a Giant High Temperature and High Salinity Clastic Reservoir to Design an ASP Pilot","authors":"M. T. Al-Murayri, H. Al-Mayyan, Narjes Al-Mahmeed, A. Muthuswamy, G. Shahin, S. Shukla","doi":"10.2118/198174-ms","DOIUrl":"https://doi.org/10.2118/198174-ms","url":null,"abstract":"\u0000 This paper discusses static and dynamic adsorption experiments to evaluate surfactant and alkali consumption as well as polymer injectivity to guide well perforation design for an Alkaline Surfactant Polymer (ASP) pilot in a giant clastic reservoir in Kuwait. Alkali and surfactant consumption in the reservoir and polymer mechanical degradation near the wellbore have a significant impact on the effectiveness of the injected ASP slug to recover additional oil from the reservoir post water flooding. Aqueous solutions consisting of alkali, surfactant and co-solvent with and without hydrolyzed polyacrylamide polymer were injected into outcrop (Bentheimer) and cleaned reservoir cores at a reservoir temperature of 90°C. The concentration of surfactant and alkali in the effluent stream was measured using potentiometric titration and the retardation of the chemical waves in comparison to the salinity tracer wave was used to estimate chemical adsorption. For the injectivity tests, ASP and polymer drive solutions were injected at various rates into cleaned reservoir core to determine threshold onset rates for screen factor and apparent viscosity loss at room temperature and at 40°C.\u0000 This laboratory study shows that surfactant adsorption can be higher when the experiments are conducted using reservoir core at the reservoir temperature of 90°C compared to literature reported adsorption values for internal olefin sulfonates (IOS) on Berea rock in the absence of alkali and polymer at room temperature. Both the static and dynamic adsorption experiments revealed that surfactant adsorption and alkali consumption was reduced in the presence of polymer. This is likely due to a competition between surfactant and polymer molecules for the adsorption sites on the rock surface. The polymer injectivity tests showed that screen factor declined above a Darcy velocity of 83 ft/day and apparent viscosity peaked at a Darcy velocity of 166 ft/day. Based on these results, it was recommended that well perforations for injection wells be designed such that flow rate does not exceed 100 - 150 ft/day to preserve the benefits of mobility control through ASP and polymer injection.","PeriodicalId":282370,"journal":{"name":"Day 2 Mon, October 14, 2019","volume":"8 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128829853","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}
Taher El Gezeery, Y. Halawa, Mohamed Al Rashidi, S. Matter, Z. Ramadan, S. Osman, A. Ahmed, N. Al-Hamad, D. Kumar, M. Siam, S. Abdelbaset
The Cenomanian Wara Formation in Minagish Field is composed mainly of coastal plain deposits, observed at field scale along with shallow marine shales and carbonate bioclastic sandy beds. They are locally disrupted by embedded channelized sandy bodies from fluvio-tidal origin. The reservoir units are represented by different channel geometries with limited areal extension. The placement and completion of horizontal and highly deviated wells in such reservoir is a challenge necessitating a collaborative approach to avoid major well bore instability issues. These issues have a significant impact on the well cost and time line. In addition, having the right placement and completion is important for optimizing the drainage contact. To address such challenges during the different stages of the drilling operation, different technologies were used. For example, while the well was drilling through the unstable Wara and Ahmadi shaley formations, a Logging While Drilling (LWD) sonic and gamma ray (GR) tools were used to update in realtime a predrill geomechanical model with the formation acoustic and GR properties. Having such measurements allowed calculating the right mud weight density which resulted in drilling a stable borehole. This was confirmed by the absence of cavings and tight spots thought out the whole operation. On the other hand, the drain section was drilled in Wara channel sands which are known to be composed of a thinly bedded faulted sand-silt sequence with the sand layers being relatively radioactive. To help steering in such complex environment, a combination of LWD tools were chosen to place the well in the sweet spot of the target. These tools involved using the advanced deep azimuthal resistivity (geosteering) and the Multi-Function LWD (advanced petrophysics) tools. As a result of this, the horizontal section was proactively geosteered in the reservoir in which 1049 ft MD were steered in the high-quality sand layers.
Minagish油田的Cenomanian Wara组主要由海岸平原沉积组成，并伴有浅海页岩和碳酸盐岩生物碎屑砂层。它们局部被河潮成因的内嵌河道化砂体破坏。储层单元由不同的河道几何形状表示，其面积扩展有限。在这样的油藏中，水平井和大斜度井的布置和完井是一个挑战，需要采用协作方法来避免主要的井筒不稳定问题。这些问题对钻井成本和作业时间都有重大影响。此外，正确的位置和完井对于优化排液接触也很重要。为了在钻井作业的不同阶段解决这些挑战，使用了不同的技术。例如，当该井在不稳定的Wara和Ahmadi页岩地层中钻井时，使用随钻测井(LWD)声波和伽马射线(GR)工具实时更新钻前地质力学模型，其中包含地层声波和GR特性。有了这样的测量，就可以计算出正确的泥浆重量密度，从而钻出一个稳定的井眼。这一点得到了证实，因为在整个作业过程中没有出现塌方和死角。另一方面，排水段是在Wara水道砂中钻探的，该砂层由薄层状断裂砂-粉砂层序组成，砂层具有相对的放射性。为了在如此复杂的环境中帮助定向，选择了LWD工具组合，将井定位在目标的最佳位置。这些工具包括先进的深部方位电阻率(地质导向)和多功能LWD(先进岩石物理)工具。因此，在高质量砂层中进行了1049 ft MD导向的水平段主动地质导向。
{"title":"A Collaborative Approach in Horizontal Drilling for Well Cost Optimization and Optimum Drainage, Minagish Field, West Kuwait","authors":"Taher El Gezeery, Y. Halawa, Mohamed Al Rashidi, S. Matter, Z. Ramadan, S. Osman, A. Ahmed, N. Al-Hamad, D. Kumar, M. Siam, S. Abdelbaset","doi":"10.2118/198182-ms","DOIUrl":"https://doi.org/10.2118/198182-ms","url":null,"abstract":"\u0000 The Cenomanian Wara Formation in Minagish Field is composed mainly of coastal plain deposits, observed at field scale along with shallow marine shales and carbonate bioclastic sandy beds. They are locally disrupted by embedded channelized sandy bodies from fluvio-tidal origin. The reservoir units are represented by different channel geometries with limited areal extension. The placement and completion of horizontal and highly deviated wells in such reservoir is a challenge necessitating a collaborative approach to avoid major well bore instability issues. These issues have a significant impact on the well cost and time line. In addition, having the right placement and completion is important for optimizing the drainage contact. To address such challenges during the different stages of the drilling operation, different technologies were used. For example, while the well was drilling through the unstable Wara and Ahmadi shaley formations, a Logging While Drilling (LWD) sonic and gamma ray (GR) tools were used to update in realtime a predrill geomechanical model with the formation acoustic and GR properties. Having such measurements allowed calculating the right mud weight density which resulted in drilling a stable borehole. This was confirmed by the absence of cavings and tight spots thought out the whole operation. On the other hand, the drain section was drilled in Wara channel sands which are known to be composed of a thinly bedded faulted sand-silt sequence with the sand layers being relatively radioactive. To help steering in such complex environment, a combination of LWD tools were chosen to place the well in the sweet spot of the target. These tools involved using the advanced deep azimuthal resistivity (geosteering) and the Multi-Function LWD (advanced petrophysics) tools. As a result of this, the horizontal section was proactively geosteered in the reservoir in which 1049 ft MD were steered in the high-quality sand layers.","PeriodicalId":282370,"journal":{"name":"Day 2 Mon, October 14, 2019","volume":"16 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116875491","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. Qureshi, M. Ali, M. A. Rahman, Ibrahim Hassan, G. Rasul, Rashid Hassan
The hole cleaning is considered a key element of drilling operation as it impacts the economics of drilling operations, operational time of operations and the safety of operations. Inadequate hole cleaning can lead to blockages resulting in loss of circulation and premature wear out of the drill pipe. The transport of solids cuttings as a multiphase flow offers a solution to the hole cleaning issue, as it can aid to lower operational cost, reduce operation time, and enhance the quality of overall drilling operations. Electrical resistance tomography (ERT) is a promising technology to visualize the 3D flow conditions involved in the hole cleaning process. ERT system is utilized to study and analyze the multiphase flow behavior and to provide in situ volume fraction distribution quantitatively through the drilling annulus. The motive of this work is to investigate the effect of different eccentricities (0-50 %), inner pipe rotation speed (0-120 RPM) and liquid flow rates (160-190 Kg/min) on the secondary phase (solids + air) transport across the annulus using the ERT system. The three-phase flow conditions (water, air, and solids) experiments were conducted in the horizontal flow loop with annulus at Texas A&M University at Qatar (TAMUQ) using ERT system. The flow loop annulus line consists of 6.16 m horizontal/inclined line. The inner diameter of the outer acrylic pipe and the outer diameter of the inner stainless steel pipe were 114.3 mm (4.5 in) and 63.5 mm (2.5 in), respectively. The glass beads (2-3 mm) were injected at a concentration of 5 wt%. The experimental results indicate that the ERT sensors have the capability of providing real-time quantitative images of annular multiphase flow regimes and it can be utilized effectively to observe the secondary phase (solids + air) transport across the opaque region of the annulus. It was also observed that the concentration of secondary phase (solids + air) tends to increase with an increase in the eccentricity of the inner pipe and the inner pipe rotation does not have a significant effect on the concentration of secondary phase (solids + air) at selected experimental conditions.
{"title":"Experimental Investigation of Multi-Phase Flow in an Annulus Using Electric Resistance Tomography","authors":"M. Qureshi, M. Ali, M. A. Rahman, Ibrahim Hassan, G. Rasul, Rashid Hassan","doi":"10.2118/198011-ms","DOIUrl":"https://doi.org/10.2118/198011-ms","url":null,"abstract":"\u0000 The hole cleaning is considered a key element of drilling operation as it impacts the economics of drilling operations, operational time of operations and the safety of operations. Inadequate hole cleaning can lead to blockages resulting in loss of circulation and premature wear out of the drill pipe. The transport of solids cuttings as a multiphase flow offers a solution to the hole cleaning issue, as it can aid to lower operational cost, reduce operation time, and enhance the quality of overall drilling operations.\u0000 Electrical resistance tomography (ERT) is a promising technology to visualize the 3D flow conditions involved in the hole cleaning process. ERT system is utilized to study and analyze the multiphase flow behavior and to provide in situ volume fraction distribution quantitatively through the drilling annulus. The motive of this work is to investigate the effect of different eccentricities (0-50 %), inner pipe rotation speed (0-120 RPM) and liquid flow rates (160-190 Kg/min) on the secondary phase (solids + air) transport across the annulus using the ERT system. The three-phase flow conditions (water, air, and solids) experiments were conducted in the horizontal flow loop with annulus at Texas A&M University at Qatar (TAMUQ) using ERT system. The flow loop annulus line consists of 6.16 m horizontal/inclined line. The inner diameter of the outer acrylic pipe and the outer diameter of the inner stainless steel pipe were 114.3 mm (4.5 in) and 63.5 mm (2.5 in), respectively. The glass beads (2-3 mm) were injected at a concentration of 5 wt%. The experimental results indicate that the ERT sensors have the capability of providing real-time quantitative images of annular multiphase flow regimes and it can be utilized effectively to observe the secondary phase (solids + air) transport across the opaque region of the annulus. It was also observed that the concentration of secondary phase (solids + air) tends to increase with an increase in the eccentricity of the inner pipe and the inner pipe rotation does not have a significant effect on the concentration of secondary phase (solids + air) at selected experimental conditions.","PeriodicalId":282370,"journal":{"name":"Day 2 Mon, October 14, 2019","volume":"91 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131725480","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}
Historically, it has been a challenge to analyze and predict water cut or water production. While predicting water production may seem less relevant as compared to oil production, produced water poses many challenges. The difficulty rises when surface facilities cannot handle the water produced and reservoir pressure declines sharply as a result of excess water production. Multiphase flowmeters (MPFMs) have in the past few decades gradually replaced the conventional approach of metering multiphase flow streams using test separators. However, MPFMs have been faced with several challenges including flow assurance problems and high bottomhole temperatures and pressures. In addition, they have a threshold below which the accuracy of the measurement of water production will be highly questionable due to design and technology limitations. As a matter of economic decisions, it is necessary to detect and estimate early and post water breakthrough trends respectively. Several models to forecast water breakthrough have been developed. Among them is the famous water cut (WC) versus cumulative production (Np) plot. This paper presents two empirical models to address the inability of MPFM to detect early water breakthrough below a threshold and to provide an alternative technique for modeling post water breakthrough. The models developed in this work predict water breakthrough using fluid volumes, bottomhole pressure and temperature. The first technique predicts early water breakthrough when the plotted function shows a deviation from a straight-line trend. In the second model, the water cut equation is modified for post water breakthrough prediction. Previous studies of water cut (WC) have focused on the production of water above the MPFMs threshold. The models derived in this paper provide accurate water cut estimates below MPMFs threshold and reliable post water breakthrough analysis.
{"title":"Holistic Approach to Estimate Water Breakthrough; A Case Study","authors":"D. Opoku, D. A. Shehri, Stephen Adjei","doi":"10.2118/198143-ms","DOIUrl":"https://doi.org/10.2118/198143-ms","url":null,"abstract":"\u0000 Historically, it has been a challenge to analyze and predict water cut or water production. While predicting water production may seem less relevant as compared to oil production, produced water poses many challenges. The difficulty rises when surface facilities cannot handle the water produced and reservoir pressure declines sharply as a result of excess water production.\u0000 Multiphase flowmeters (MPFMs) have in the past few decades gradually replaced the conventional approach of metering multiphase flow streams using test separators. However, MPFMs have been faced with several challenges including flow assurance problems and high bottomhole temperatures and pressures. In addition, they have a threshold below which the accuracy of the measurement of water production will be highly questionable due to design and technology limitations. As a matter of economic decisions, it is necessary to detect and estimate early and post water breakthrough trends respectively. Several models to forecast water breakthrough have been developed. Among them is the famous water cut (WC) versus cumulative production (Np) plot.\u0000 This paper presents two empirical models to address the inability of MPFM to detect early water breakthrough below a threshold and to provide an alternative technique for modeling post water breakthrough. The models developed in this work predict water breakthrough using fluid volumes, bottomhole pressure and temperature. The first technique predicts early water breakthrough when the plotted function shows a deviation from a straight-line trend. In the second model, the water cut equation is modified for post water breakthrough prediction.\u0000 Previous studies of water cut (WC) have focused on the production of water above the MPFMs threshold. The models derived in this paper provide accurate water cut estimates below MPMFs threshold and reliable post water breakthrough analysis.","PeriodicalId":282370,"journal":{"name":"Day 2 Mon, October 14, 2019","volume":"50 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116310932","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}
B. Gerlach, Fatima Dugonjić‐Bilić, M. Neuber, Ahmad Alkouh
Synthetic polymers in the emulsion form have been exploited for enhanced oil recovery applications especially in harsh environments for instance offshore or remote onshore locations. Polymer solutions can be prepared on-the-fly using saline make-up water like formation water or sea water. Use of an inverter surfactant accelerates the inversion of the polymer emulsion. For this study two highly efficient inverter surfactants at different price level were selected and their impact on the performance of an acrylamide-based emulsion copolymer was investigated. Polymer solutions prepared with the inverter surfactants S1 and S2 at different concentrations and conditioned by defined shear treatment were characterized by rheology, filter tests and injectivity behavior in sand packs. Significant impact of inverter surfactant on rheological properties and especially on injectivity performance is demonstrated. Viscosities of polymer solutions prepared with surfactant S1 are slightly higher (than viscosities with surfactant S2) and decrease with increasing surfactant concentration at constant polymer content. Besides, RRF values as a measure for injectivity behavior strongly decrease at ascending surfactant content. More intense conditioning leads to favorable injectivity of an otherwise plugging polymer solution. At lower concentrations surfactant S1 seems to adversely interact with the polymer and form polymer-surfactant complexes which are retained in the sand pack during injection. For surfactant S2 viscosities of polymer solutions are independent of surfactant concentration and RRF values are low even at low surfactant concentration. This surfactant ensures good injectivities over a broad range of conditions. Being the economically more favorable surfactant it adds value to polymer flooding projects.
{"title":"Best Surfactant for EOR Polymer Injectivity","authors":"B. Gerlach, Fatima Dugonjić‐Bilić, M. Neuber, Ahmad Alkouh","doi":"10.2118/198097-ms","DOIUrl":"https://doi.org/10.2118/198097-ms","url":null,"abstract":"\u0000 Synthetic polymers in the emulsion form have been exploited for enhanced oil recovery applications especially in harsh environments for instance offshore or remote onshore locations. Polymer solutions can be prepared on-the-fly using saline make-up water like formation water or sea water. Use of an inverter surfactant accelerates the inversion of the polymer emulsion. For this study two highly efficient inverter surfactants at different price level were selected and their impact on the performance of an acrylamide-based emulsion copolymer was investigated.\u0000 Polymer solutions prepared with the inverter surfactants S1 and S2 at different concentrations and conditioned by defined shear treatment were characterized by rheology, filter tests and injectivity behavior in sand packs.\u0000 Significant impact of inverter surfactant on rheological properties and especially on injectivity performance is demonstrated. Viscosities of polymer solutions prepared with surfactant S1 are slightly higher (than viscosities with surfactant S2) and decrease with increasing surfactant concentration at constant polymer content. Besides, RRF values as a measure for injectivity behavior strongly decrease at ascending surfactant content. More intense conditioning leads to favorable injectivity of an otherwise plugging polymer solution. At lower concentrations surfactant S1 seems to adversely interact with the polymer and form polymer-surfactant complexes which are retained in the sand pack during injection.\u0000 For surfactant S2 viscosities of polymer solutions are independent of surfactant concentration and RRF values are low even at low surfactant concentration. This surfactant ensures good injectivities over a broad range of conditions. Being the economically more favorable surfactant it adds value to polymer flooding projects.","PeriodicalId":282370,"journal":{"name":"Day 2 Mon, October 14, 2019","volume":"15 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-10-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130358353","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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