D. Abdrazakov, E. Karpekin, A. Filimonov, Ivan Pertsev, A. Burlibayev, M. Aimagambetov, V. Blinov, B. Akbayev, A. Timonin, D. Ezersky
The presence of conductive and extended heterogeneous features not connected to the wellbore and located beyond the investigation depths of standard characterization tools can be the reason for unexpected loss of net pressure during stimulation treatments due to the hydraulic fracture breakthrough into these heterogeneous areas. In current field practice, if such breakthrough occurs, it is considered as bad luck without the possibility of the quantitative analysis. This mindset can be changed in favor of the stimulation and reservoir management success using an approach that ties the thorough fracture pressure analysis with the output of the specific acoustic reflectivity survey capable of identifying position, shape, and orientation of far-field heterogeneous features. The approach consists of four steps and is applicable to cases when the hydraulic fracture experiences breakthrough into the heterogeneity. First, before the stimulation treatments, at the reservoir characterization stage, a borehole acoustic reflectivity survey is run. Gathered data are interpreted and visualized according to a specific workflow that yields the image of the heterogeneous areas located around the wellbore in the radius of several tens of meters. Second, the hydraulic fracturing treatment is performed, and fracture pressure analysis is performed, which identifies the pressure drops typical for the breakthrough. Third, after the breakthrough into the heterogeneity is confirmed, the distance to this heterogeneity is used as a marker for calibration of the fracture properties and geometry. Finally, the post-stimulation pressure and production data are used to define the properties of the heterogeneous features, such as conductivity and approximate dimensions. The comprehensive field application example of the suggested approach confirmed its effectiveness. For the tight carbonate formations, the heterogeneity in a form of fracture corridor was revealed by the acoustic reflectivity survey at least 20 m away from the wellbore. The breakthrough into this heterogeneity was observed during the acid fracturing treatment. The distance to the heterogeneity and observed pumping time to breakthrough were used as markers characterizing fracture propagation; reservoir and rock properties were adjusted using a fracturing simulator to obtain this fracture propagation. Finally, the post-stimulation production data were analyzed to determine infinite conductivity of the fracture corridor and quantify its extent downward. Data gathered during reservoir and hydraulic fracture properties calibration allowed for optimization of stimulation strategy of the target layer throughout the field; the information about the heterogeneity’s properties allowed for optimization of the completion and reservoir development strategy.
{"title":"Integration of Borehole Acoustic Reflectivity Survey and Fracture Pressure Analysis to Determine Properties of Far-Field Heterogeneities During Stimulation in Tight Reservoirs","authors":"D. Abdrazakov, E. Karpekin, A. Filimonov, Ivan Pertsev, A. Burlibayev, M. Aimagambetov, V. Blinov, B. Akbayev, A. Timonin, D. Ezersky","doi":"10.2118/204624-ms","DOIUrl":"https://doi.org/10.2118/204624-ms","url":null,"abstract":"\u0000 The presence of conductive and extended heterogeneous features not connected to the wellbore and located beyond the investigation depths of standard characterization tools can be the reason for unexpected loss of net pressure during stimulation treatments due to the hydraulic fracture breakthrough into these heterogeneous areas. In current field practice, if such breakthrough occurs, it is considered as bad luck without the possibility of the quantitative analysis. This mindset can be changed in favor of the stimulation and reservoir management success using an approach that ties the thorough fracture pressure analysis with the output of the specific acoustic reflectivity survey capable of identifying position, shape, and orientation of far-field heterogeneous features.\u0000 The approach consists of four steps and is applicable to cases when the hydraulic fracture experiences breakthrough into the heterogeneity. First, before the stimulation treatments, at the reservoir characterization stage, a borehole acoustic reflectivity survey is run. Gathered data are interpreted and visualized according to a specific workflow that yields the image of the heterogeneous areas located around the wellbore in the radius of several tens of meters. Second, the hydraulic fracturing treatment is performed, and fracture pressure analysis is performed, which identifies the pressure drops typical for the breakthrough. Third, after the breakthrough into the heterogeneity is confirmed, the distance to this heterogeneity is used as a marker for calibration of the fracture properties and geometry. Finally, the post-stimulation pressure and production data are used to define the properties of the heterogeneous features, such as conductivity and approximate dimensions.\u0000 The comprehensive field application example of the suggested approach confirmed its effectiveness. For the tight carbonate formations, the heterogeneity in a form of fracture corridor was revealed by the acoustic reflectivity survey at least 20 m away from the wellbore. The breakthrough into this heterogeneity was observed during the acid fracturing treatment. The distance to the heterogeneity and observed pumping time to breakthrough were used as markers characterizing fracture propagation; reservoir and rock properties were adjusted using a fracturing simulator to obtain this fracture propagation. Finally, the post-stimulation production data were analyzed to determine infinite conductivity of the fracture corridor and quantify its extent downward. Data gathered during reservoir and hydraulic fracture properties calibration allowed for optimization of stimulation strategy of the target layer throughout the field; the information about the heterogeneity’s properties allowed for optimization of the completion and reservoir development strategy.","PeriodicalId":11320,"journal":{"name":"Day 3 Tue, November 30, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85917259","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}
Haitao Wang, S. Zhang, X. Bian, Shuangming Li, Yulin Tu, Xiong Zhang, Zhifa Wang
Under the condition of high ambient temperature and high confining pressure，the physical & mechanical properties and in-situ stress state of deep shale will change noticeably. Normally, the deep-shale formation has high horizontal stress difference (about 11∼21 MPa, 1595∼3045 psi), high fracture-closure pressure gradient (about 0.023∼0.025 MPa/m, 1.017∼1.105 psi/ft), high breakdown pressure gradient (larger than 0.03 MPa/m, 1.327 psi/ft), low mechanical brittleness (about 42%∼55%), low difference between the vertical and the horizontal stresses (about 3∼5MPa, 435∼725 psi). The complex geological characteristics of deep shale increase the difficulity of fracturing: 1) effect of brittle/ductile transition under high confining pressure; 2) non-uniform propagation of multi-cluster fractures is more prominent; 3) the migration of proppant is difficult in narrow fracture network; 4) high friction and high pumping pressure; 5) more stringent requirements for fracturing tools; 6) high requirements for fracturing scale, efficiency and economy. To address above challenges, this paper presents a comprehensive overview of latest researching and applicable techniques about deep-shale fracturing (3500
{"title":"Development of Fracturing Technology for Deep Shale Gas in South Sichuan, China","authors":"Haitao Wang, S. Zhang, X. Bian, Shuangming Li, Yulin Tu, Xiong Zhang, Zhifa Wang","doi":"10.2118/204804-ms","DOIUrl":"https://doi.org/10.2118/204804-ms","url":null,"abstract":"\u0000 Under the condition of high ambient temperature and high confining pressure，the physical & mechanical properties and in-situ stress state of deep shale will change noticeably. Normally, the deep-shale formation has high horizontal stress difference (about 11∼21 MPa, 1595∼3045 psi), high fracture-closure pressure gradient (about 0.023∼0.025 MPa/m, 1.017∼1.105 psi/ft), high breakdown pressure gradient (larger than 0.03 MPa/m, 1.327 psi/ft), low mechanical brittleness (about 42%∼55%), low difference between the vertical and the horizontal stresses (about 3∼5MPa, 435∼725 psi). The complex geological characteristics of deep shale increase the difficulity of fracturing: 1) effect of brittle/ductile transition under high confining pressure; 2) non-uniform propagation of multi-cluster fractures is more prominent; 3) the migration of proppant is difficult in narrow fracture network; 4) high friction and high pumping pressure; 5) more stringent requirements for fracturing tools; 6) high requirements for fracturing scale, efficiency and economy.\u0000 To address above challenges, this paper presents a comprehensive overview of latest researching and applicable techniques about deep-shale fracturing (3500<TVD<3800 m, 11482∼12467 ft), including: 1) new evaluation methods on fractured shale quality and fracability, considering vertical stress difference coefficient and effective confining stress; 2) non-uniform propagation of fractures in multi-clusters perforation; 3) reveal the transport mechanism of proppant in narrow fracture network; 4) optimization of high performance fracturing fluid systems to enlarge the ESRV in deep shale; 5) development of a new staged fracturing tool for deep-shale fracturing, including dissoluble bridge plug and toe delayed sleeve; 6) an integrated geoscience and engineering simulation to optimize the treatment parameters and to achieve the best fracturing efficiency in the deep shale strata.\u0000 The hydraulic fracturing technique for deep shale gas with the depth of 3500∼4500 m (11482∼14763 ft) has formed preliminarily. The hydraulic fracturing technology for deep shale gas (TVD≥3500∼3800 m, 11482∼12467 ft) have made a breakthrough in Sichuan basin, China, and significant progress has also made in 3800-4500m TVD (12467∼14763 ft). The research results and techniques introduced in the paper have been successfully applied to more than 100 wells in the Sichuan basin. The test production of part fractured well can reach (10∼31)×104 m3 per day (0.35∼1.09×107 SCF/day), which basically realizes the economical and effective development for deep shale gas.","PeriodicalId":11320,"journal":{"name":"Day 3 Tue, November 30, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76054541","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}
Tawakol Abdallah, A. Al-Fawwaz, Galal Eldaw, Wael Abdallah
Al-Khafji Joint Operations (KJO), a joint operation representing both Saudi and Kuwaiti energy interests in the divided zone, recently encountered obstructions in their offshore field. Routine pressure and temperature surveys revealed that an increasing number of wells were developing scale. The operation required an efficient mechanical tool to clean out extensive accumulated scale bridging within a vertical production string and restore full wellbore accessibility. The well had been previously shut down from operations for five years. The operator considered using a coiled tubing (CT) unit or workover rig to clear the scale but sought a more cost-effective solution. The operator chose a slickline wellbore cleanup and debris breaking tool, which is an impact-driven tool designed to break up scale deposits in a cost-effective, efficient manner. It is jarred down mechanically in the well, each jar applying a short-duration torque via the unique, helically split torque sub. The well's accessible tubing inner diameter was reduced from 2.9-in, nominal to 2-in, at the wireline reentry guide depth. To combat this issue, the slickline technology was deployed with subs increasing in outer diameter (OD) from 1.9-in. to 2.5-in. OD tools. The special features of the wellbore cleanup and debris breaking tool made it better adapted to the well environment and greatly increased the descaling efficiency. Thirty runs enabled the team to clear the scale accumulations down to 3,652 ft (1113 m). The operator confirmed integrity of the tubing at the end of the slickline operation, allowing the slickline team to access the wellbore and run a memory pressure temperature survey to check the well deliverability. The implementation of the wellbore cleanup and debris breaking tool enabled the operator to reduce inventory and overall descaling time. Microscopic and Fourier transform infrared analyses of the scale determined it was calcite (CaCO3) with some small hydrocarbon impurities from either oil or diesel. The descaling rate and cost savings achieved using the wellbore cleanup and debris breaking tool has since resulted in the operator adopting this technology and looking into the feasibility of starting a campaign for scale removal in more than 20 wells. The presence of calcite as a scaling agent is potentially due to the carbonate-saturated formation water and the loss of carbon dioxide from this water to the hydrocarbon phase as pressure decreases. Creating a detailed reservoir characterization that defines fracture orientation, relative aperture produced fluid analysis, and rock properties can help minimize the effect of scale at an early stage. Continuous well monitoring can lead to early identification of scale and determine the need for chemical treatment or further mechanical interventions. This case study demonstrates the benefits of using this wellbore cleanup and debris breaking tool as the first method of mechanical descaling.
{"title":"Slickline Descaling Technology Delivers Cost Savings Over Coiled Tubing","authors":"Tawakol Abdallah, A. Al-Fawwaz, Galal Eldaw, Wael Abdallah","doi":"10.2118/204888-ms","DOIUrl":"https://doi.org/10.2118/204888-ms","url":null,"abstract":"\u0000 Al-Khafji Joint Operations (KJO), a joint operation representing both Saudi and Kuwaiti energy interests in the divided zone, recently encountered obstructions in their offshore field. Routine pressure and temperature surveys revealed that an increasing number of wells were developing scale. The operation required an efficient mechanical tool to clean out extensive accumulated scale bridging within a vertical production string and restore full wellbore accessibility. The well had been previously shut down from operations for five years. The operator considered using a coiled tubing (CT) unit or workover rig to clear the scale but sought a more cost-effective solution.\u0000 The operator chose a slickline wellbore cleanup and debris breaking tool, which is an impact-driven tool designed to break up scale deposits in a cost-effective, efficient manner. It is jarred down mechanically in the well, each jar applying a short-duration torque via the unique, helically split torque sub. The well's accessible tubing inner diameter was reduced from 2.9-in, nominal to 2-in, at the wireline reentry guide depth. To combat this issue, the slickline technology was deployed with subs increasing in outer diameter (OD) from 1.9-in. to 2.5-in. OD tools.\u0000 The special features of the wellbore cleanup and debris breaking tool made it better adapted to the well environment and greatly increased the descaling efficiency. Thirty runs enabled the team to clear the scale accumulations down to 3,652 ft (1113 m). The operator confirmed integrity of the tubing at the end of the slickline operation, allowing the slickline team to access the wellbore and run a memory pressure temperature survey to check the well deliverability. The implementation of the wellbore cleanup and debris breaking tool enabled the operator to reduce inventory and overall descaling time.\u0000 Microscopic and Fourier transform infrared analyses of the scale determined it was calcite (CaCO3) with some small hydrocarbon impurities from either oil or diesel. The descaling rate and cost savings achieved using the wellbore cleanup and debris breaking tool has since resulted in the operator adopting this technology and looking into the feasibility of starting a campaign for scale removal in more than 20 wells.\u0000 The presence of calcite as a scaling agent is potentially due to the carbonate-saturated formation water and the loss of carbon dioxide from this water to the hydrocarbon phase as pressure decreases. Creating a detailed reservoir characterization that defines fracture orientation, relative aperture produced fluid analysis, and rock properties can help minimize the effect of scale at an early stage. Continuous well monitoring can lead to early identification of scale and determine the need for chemical treatment or further mechanical interventions. This case study demonstrates the benefits of using this wellbore cleanup and debris breaking tool as the first method of mechanical descaling.","PeriodicalId":11320,"journal":{"name":"Day 3 Tue, November 30, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91527214","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}
O. Abdullatif, M. Osman, M. Bashri, Ammar Abdlmutalib, M. Yassin
Siliciclastic sediments represent important lithological unit of the Red Sea coastal plain. Their subsurface equivalents are important targets of groundwater aquifer and hydrocarbon reservoirs in the region. The lithofacies of the modern fluvial deltaic system has several distinct geomorphic units and sub-environments such as alluvial, fluvial, delta plain, aeolian, intertidal, coastal sabkha and eustuarine sediments. This study intends to characterize the lithofacies and the depositional environments and to produce an integrated facies model for this modern fluvial-deltaic system. The study might provide a valuable modern analog to several important subsurface Neogene formations that act as important hydrocarbon reservoirs and groundwater aquifers. The study integrates information and data obtained from landsats, maps and detailed field observation and measurements of facies analysis of the fluvial and deltaic along traveses from the Arabian Shield to the Red Sea coast. The lithofacies sediment analysis revealed four main lithofacies associations namely lithofacies A,B,C ad D. Lithoacies Associations A, which represents the oldest unit is dominated by coarse gravel with minor sands facies. While the lithofacies B is dominated byfine gravel and sand lithofacies, occasionally pebbly, vary from horizontal, planar to massive sands with minor laminated to massive silts and mud facies. The lithofacies in A and B show lateral proximal to distal variation as well as characteristic vertical stacking patterns. The Facies Association A and B indicates a change in fluvial depositional styles from gravelly alluvial fans to gravelly sandy fluvial systems. The lithofacies association C represents the recent fluvial system which consists of minor gravel lag deposits associated maily with various sand lithofacies of planner, horizontal and massive sand associated with massive and limainted sand and mud lithofacies. The lithofacies Association D is dominated with Barchan sand dunes local interfigger with muddy iinterdunes and sand sheets. Lithofacies D occupies rather more distal geomporphic position of the fluvial deltaic system that is adjace to coastal sabkha. The lithofacies associations described here document the evolution and development of the coastal plain sediments through space and time under various autocyclic and allocyclic controls. This included the tectonics and structural development associated with the Red Sea rifting and opening since the Oligocene – Miocene time. Others controls include the evolution of the Arabian shield (provenance) and the coastal plain through space and time as controlled by tectonics, sediment supply, climate and locally by autocyclic environmental This study might be beneficial for understanding the controls and stratigraphic evolution of the Red Sea region and will be of great value for reservoir and aquifer characterization, development and management. This modern analog model can also help in providing geological ba
{"title":"Sedimentology and Evolution of the Fluvial-Deltaic System: A Modern Depositional Model Analog from the Red Sea Coastal Region, Saudi Arabia","authors":"O. Abdullatif, M. Osman, M. Bashri, Ammar Abdlmutalib, M. Yassin","doi":"10.2118/204558-ms","DOIUrl":"https://doi.org/10.2118/204558-ms","url":null,"abstract":"\u0000 Siliciclastic sediments represent important lithological unit of the Red Sea coastal plain. Their subsurface equivalents are important targets of groundwater aquifer and hydrocarbon reservoirs in the region. The lithofacies of the modern fluvial deltaic system has several distinct geomorphic units and sub-environments such as alluvial, fluvial, delta plain, aeolian, intertidal, coastal sabkha and eustuarine sediments. This study intends to characterize the lithofacies and the depositional environments and to produce an integrated facies model for this modern fluvial-deltaic system. The study might provide a valuable modern analog to several important subsurface Neogene formations that act as important hydrocarbon reservoirs and groundwater aquifers. The study integrates information and data obtained from landsats, maps and detailed field observation and measurements of facies analysis of the fluvial and deltaic along traveses from the Arabian Shield to the Red Sea coast. The lithofacies sediment analysis revealed four main lithofacies associations namely lithofacies A,B,C ad D. Lithoacies Associations A, which represents the oldest unit is dominated by coarse gravel with minor sands facies. While the lithofacies B is dominated byfine gravel and sand lithofacies, occasionally pebbly, vary from horizontal, planar to massive sands with minor laminated to massive silts and mud facies. The lithofacies in A and B show lateral proximal to distal variation as well as characteristic vertical stacking patterns. The Facies Association A and B indicates a change in fluvial depositional styles from gravelly alluvial fans to gravelly sandy fluvial systems. The lithofacies association C represents the recent fluvial system which consists of minor gravel lag deposits associated maily with various sand lithofacies of planner, horizontal and massive sand associated with massive and limainted sand and mud lithofacies. The lithofacies Association D is dominated with Barchan sand dunes local interfigger with muddy iinterdunes and sand sheets. Lithofacies D occupies rather more distal geomporphic position of the fluvial deltaic system that is adjace to coastal sabkha. The lithofacies associations described here document the evolution and development of the coastal plain sediments through space and time under various autocyclic and allocyclic controls. This included the tectonics and structural development associated with the Red Sea rifting and opening since the Oligocene – Miocene time. Others controls include the evolution of the Arabian shield (provenance) and the coastal plain through space and time as controlled by tectonics, sediment supply, climate and locally by autocyclic environmental This study might be beneficial for understanding the controls and stratigraphic evolution of the Red Sea region and will be of great value for reservoir and aquifer characterization, development and management. This modern analog model can also help in providing geological ba","PeriodicalId":11320,"journal":{"name":"Day 3 Tue, November 30, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83759808","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. Alsaeedi, E. Latypov, M. Elabrashy, M. Alzeyoudi, A. Al-Ameri, M. Albadi, A. A. Al Bairaq, Sandeep Soni, Jose Isambertt, Deepak Tripathi, M. Hidalgo, Hamda Alkuwaiti
There are several operational challenges associated with a gas field producing in recycle or depletion mode, including a reasonable forecast and a robust production strategy planning. The complex reservoir dynamics further demands faster and reasonable analysis and decision-making. This paper discusses an all-inclusive integrated modeling approach to devise a production strategy incorporating the detailed compressor design requirements to ensure that a consistent production-stream is available in the long-term considering technical and economic aspects. The proposed production strategy is a two-fold approach. In the first step, the process utilizes the current reservoir simulation data in the production-forecast model. This history matched model captures the reservoir dynamics such as reservoir pressure decline and accounts for future wells drilling-requirements. However, the detailed production hydraulics in wellbore and surface facilities is not captured in the model. Further, to consider the declining well-performance and facility bottlenecks, integrated analysis is required. So, in the second step, the reservoir simulation model is dynamically integrated to take the input from the production model, encompassing detailed well and surface facility digital twins. The continuous interaction provides a highly reliable production profile that can be used to produce a production strategy of compressor design for the future. A strong interactive user-interface in the digital platform enables the user to configure various what-if scenarios efficiently, considering all anticipated future events and production conditions. The major output of the process was the accurate identification of the pressure-profile at multiple surface facility locations over the course of the production. Using the business-plan, field development strategy, production-profile, and the reservoir simulation output, reliable pressure-profiles were obtained, giving an indication of the declining pressures at gathering manifold over time. A well level production-profile-forecast helped in prioritizing wells for rerouting as well as workover requirements. As an outcome of this study, several manifolds were identified that are susceptible to high-pressure decline caused by declining reservoir pressures. To capture this pressure decline, a compressor mechanism was put in place to transfer the fluid to its delivery point. As this study utilizes several timesteps for the production forecast estimation, flexible routine options are also provided to the engineers to ensure that backpressure is minimized to avoid a larger back pressure on the wells for quick gains. This solution improves the efficiency of the previous approaches that were entirely relying on the reservoir simulation model to capture the pressure decline at the wellhead to forecast the compressor needs. In this methodology, the pressure profile at each node was captured to simulate a real production scenario. This holis
{"title":"Long Term Production Strategy - Application of a Dynamically Integrated Reservoir and Production Model to Identify Compression Requirements and to Address Production Deferral in a Giant Gas Field","authors":"A. Alsaeedi, E. Latypov, M. Elabrashy, M. Alzeyoudi, A. Al-Ameri, M. Albadi, A. A. Al Bairaq, Sandeep Soni, Jose Isambertt, Deepak Tripathi, M. Hidalgo, Hamda Alkuwaiti","doi":"10.2118/204533-ms","DOIUrl":"https://doi.org/10.2118/204533-ms","url":null,"abstract":"\u0000 There are several operational challenges associated with a gas field producing in recycle or depletion mode, including a reasonable forecast and a robust production strategy planning. The complex reservoir dynamics further demands faster and reasonable analysis and decision-making. This paper discusses an all-inclusive integrated modeling approach to devise a production strategy incorporating the detailed compressor design requirements to ensure that a consistent production-stream is available in the long-term considering technical and economic aspects.\u0000 The proposed production strategy is a two-fold approach. In the first step, the process utilizes the current reservoir simulation data in the production-forecast model. This history matched model captures the reservoir dynamics such as reservoir pressure decline and accounts for future wells drilling-requirements. However, the detailed production hydraulics in wellbore and surface facilities is not captured in the model. Further, to consider the declining well-performance and facility bottlenecks, integrated analysis is required. So, in the second step, the reservoir simulation model is dynamically integrated to take the input from the production model, encompassing detailed well and surface facility digital twins. The continuous interaction provides a highly reliable production profile that can be used to produce a production strategy of compressor design for the future. A strong interactive user-interface in the digital platform enables the user to configure various what-if scenarios efficiently, considering all anticipated future events and production conditions.\u0000 The major output of the process was the accurate identification of the pressure-profile at multiple surface facility locations over the course of the production. Using the business-plan, field development strategy, production-profile, and the reservoir simulation output, reliable pressure-profiles were obtained, giving an indication of the declining pressures at gathering manifold over time. A well level production-profile-forecast helped in prioritizing wells for rerouting as well as workover requirements. As an outcome of this study, several manifolds were identified that are susceptible to high-pressure decline caused by declining reservoir pressures. To capture this pressure decline, a compressor mechanism was put in place to transfer the fluid to its delivery point. As this study utilizes several timesteps for the production forecast estimation, flexible routine options are also provided to the engineers to ensure that backpressure is minimized to avoid a larger back pressure on the wells for quick gains. This solution improves the efficiency of the previous approaches that were entirely relying on the reservoir simulation model to capture the pressure decline at the wellhead to forecast the compressor needs. In this methodology, the pressure profile at each node was captured to simulate a real production scenario.\u0000 This holis","PeriodicalId":11320,"journal":{"name":"Day 3 Tue, November 30, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88606372","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
The development of any country lies in all members of society in a country, the old generation to the younger and new ones. After launching the vision of 2030 pillars, the circle of women barriers becomes wider and unlimited in the field of employment. In order to merge women in the oil and gas industry, the first milestone must be considered is creating opportunities in the labour market alongside educating and training them to acquire great learning and hone skills that qualify the women to be in the industrial workforce. It will widely contribute to the socio-economic change in a country. The female has individual skills and capabilities that the companies’ needs to achieve its business objectives. The institutes which are fundamentally structured; can open another facility which is targeted the female vocational and technical training based on the same assets (strategies & policies). Another way to do so is through collaboration with international vocational institutions, local female universities and colleges. These days there is no doubt that the oil and gas companies are critically needed for the local talents and diversity of its range. As an example, SPSP has planned to inaugurate a new female vocational & technical center, in the meantime will offer a major source of job opportunities for well trained and qualified young Saudi women that how we encourage and retain more Saudi female to the petroleum energy sector. The training programs will include Health & Safety, and Electrical Diploma. There is a lack of trained and qualified Saudi female technical workforce at the industry sector. To solve this problem, the education and the labour sectors must work simultaneously to empower the female in this field. Many companies need to retool the female candidates from functional roles such as HR or Finance to target them into practice hands-on roles. To sum up, as Vision 2030 of rewarding opportunities to the women stated, ‘’ we are directing significant investment toward unlocking their talents and supporting their contribution to the Kingdom’s economic growth.’’ Business leaders should call for an action to increase female’s opportunity at the energy sector side by side the government’s efforts in the female vocational training programs.
{"title":"Female Vocational Training","authors":"Khalid Al-Abdulwahed, Nouf Al-Ashwan","doi":"10.2118/204528-ms","DOIUrl":"https://doi.org/10.2118/204528-ms","url":null,"abstract":"\u0000 The development of any country lies in all members of society in a country, the old generation to the younger and new ones. After launching the vision of 2030 pillars, the circle of women barriers becomes wider and unlimited in the field of employment. In order to merge women in the oil and gas industry, the first milestone must be considered is creating opportunities in the labour market alongside educating and training them to acquire great learning and hone skills that qualify the women to be in the industrial workforce. It will widely contribute to the socio-economic change in a country.\u0000 The female has individual skills and capabilities that the companies’ needs to achieve its business objectives. The institutes which are fundamentally structured; can open another facility which is targeted the female vocational and technical training based on the same assets (strategies & policies). Another way to do so is through collaboration with international vocational institutions, local female universities and colleges. These days there is no doubt that the oil and gas companies are critically needed for the local talents and diversity of its range. As an example, SPSP has planned to inaugurate a new female vocational & technical center, in the meantime will offer a major source of job opportunities for well trained and qualified young Saudi women that how we encourage and retain more Saudi female to the petroleum energy sector. The training programs will include Health & Safety, and Electrical Diploma. There is a lack of trained and qualified Saudi female technical workforce at the industry sector. To solve this problem, the education and the labour sectors must work simultaneously to empower the female in this field. Many companies need to retool the female candidates from functional roles such as HR or Finance to target them into practice hands-on roles.\u0000 To sum up, as Vision 2030 of rewarding opportunities to the women stated, ‘’ we are directing significant investment toward unlocking their talents and supporting their contribution to the Kingdom’s economic growth.’’ Business leaders should call for an action to increase female’s opportunity at the energy sector side by side the government’s efforts in the female vocational training programs.","PeriodicalId":11320,"journal":{"name":"Day 3 Tue, November 30, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87236973","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}
K. Yateem, M. Dabbous, M. Kadem, Mohammed Khanferi
The main objective of the paper is to outline initiatives associated with leveraging creativity and innovation to sustain operational excellence. It will cover processes, applications and best practices toward continually leveraging creative and innovation such as the development of innovation team toward creating a collaborative environment in the generation, identification and development of ideas and new technological advancement deployment. The processes described will cover (1) the continuous monitoring and management update of innovation submissions, implementation and self-development course completion, (2) recognition for value addition resultant from technological deployment, (3) Technical Review Committee (TRC) centralization and streamlining of evaluating technologies and best practices, (4) the assignment of challenging targets and (5) the initiation of special innovation campaigns for pressing and challenging matters has resulted in various major accomplishments. The establishment of the 4th Industrial Revolution (IR 4.0) team to address production engineering and well services challenges and collaborate for articulate, smart, more efficient and effective resolutions, process improvements and decision making. The results were remarkable with an incremental increase into intent to submit a patent file consideration, patenting, technology deployment and production of technical manuscripts addressing the unique achievements as well as the submission of awards applications. Technical collaboration toward triggering resolutions to ongoing operational challenges has resulted in various internal in-house built strides of best practices and other collaborative initiatives with other services providers such as: Intelligent Field Equipment Industrial Professionals Training: Special training for intelligent field equipment associated with smart well completion (SWC) exercising and optimization, data retrieval from multiphase flow meters (MPFMs) as well as a permanent downhole monitoring system (PDHMS) and conducting basic preventative maintenance (PM) requirements. Multiphase Flow Metering (MPFM) Advanced Monitoring System: An in-house developed MPFM system advanced monitoring to enable production/Intelligent Field engineers to monitor and diagnose MPFMs healthiness in all fields. It includes a validation mechanism to monitor and verify the different MPFM diagnostic data, alarming mechanism, flow rates and data visualization tools to verify the health of the installed base of equipment toward higher testing efficiency, reduction of manpower exposure to the field, and cost avoidance through minimizing operational logistical arrangements and minimization of unnecessary field visits by service providers. The ultimate intent is to heavily depend upon all employees to successfully propose solutions, and subject matter experts to coach employees in the successful implementation of practical resolutions to improve operations, optimize cost, and
{"title":"Adoption of Innovation and Technological Advancement Deployment","authors":"K. Yateem, M. Dabbous, M. Kadem, Mohammed Khanferi","doi":"10.2118/204869-ms","DOIUrl":"https://doi.org/10.2118/204869-ms","url":null,"abstract":"\u0000 The main objective of the paper is to outline initiatives associated with leveraging creativity and innovation to sustain operational excellence. It will cover processes, applications and best practices toward continually leveraging creative and innovation such as the development of innovation team toward creating a collaborative environment in the generation, identification and development of ideas and new technological advancement deployment.\u0000 The processes described will cover (1) the continuous monitoring and management update of innovation submissions, implementation and self-development course completion, (2) recognition for value addition resultant from technological deployment, (3) Technical Review Committee (TRC) centralization and streamlining of evaluating technologies and best practices, (4) the assignment of challenging targets and (5) the initiation of special innovation campaigns for pressing and challenging matters has resulted in various major accomplishments. The establishment of the 4th Industrial Revolution (IR 4.0) team to address production engineering and well services challenges and collaborate for articulate, smart, more efficient and effective resolutions, process improvements and decision making.\u0000 The results were remarkable with an incremental increase into intent to submit a patent file consideration, patenting, technology deployment and production of technical manuscripts addressing the unique achievements as well as the submission of awards applications. Technical collaboration toward triggering resolutions to ongoing operational challenges has resulted in various internal in-house built strides of best practices and other collaborative initiatives with other services providers such as:\u0000 Intelligent Field Equipment Industrial Professionals Training:\u0000 Special training for intelligent field equipment associated with smart well completion (SWC) exercising and optimization, data retrieval from multiphase flow meters (MPFMs) as well as a permanent downhole monitoring system (PDHMS) and conducting basic preventative maintenance (PM) requirements. Multiphase Flow Metering (MPFM) Advanced Monitoring System: An in-house developed MPFM system advanced monitoring to enable production/Intelligent Field engineers to monitor and diagnose MPFMs healthiness in all fields. It includes a validation mechanism to monitor and verify the different MPFM diagnostic data, alarming mechanism, flow rates and data visualization tools to verify the health of the installed base of equipment toward higher testing efficiency, reduction of manpower exposure to the field, and cost avoidance through minimizing operational logistical arrangements and minimization of unnecessary field visits by service providers. The ultimate intent is to heavily depend upon all employees to successfully propose solutions, and subject matter experts to coach employees in the successful implementation of practical resolutions to improve operations, optimize cost, and ","PeriodicalId":11320,"journal":{"name":"Day 3 Tue, November 30, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87254271","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}
V. Keerthivasan, D. Young, Cathrine Mehus, Bjørnar Gjedrem, Moetaz Abdelghany, Henry Khov
To access a larger amount of pay zone, well trajectories are becoming longer and more complex, creating greater challenges for running completion liners. A liner shoe is a casing accessory tool that aids in the running of completion liners in long wells by allowing auto-filling of the liner and enabling pumping through the bottom of the liner. Upon reaching planned liner depth, the liner shoe is closed to allow for pressure testing and subsequent completion operations. Conventional methods used to close a liner shoe involve well intervention to set plugs or by dropping a ball, and there are inherent costs and risks associated with these operations. This paper presents the development and deployment of a remotely activated electronic liner shoe (ELS) for offshore applications that enables interventionless closing of the liner shoe, thereby improving operational efficiency, and reducing potential operational issues that could occur while closing the liner shoe conventionally. The ELS allows the operator to precisely control when the liner shoe closes – either based on pre-programmed pressure signals, a timer, or a combination of the two. A major operator in the Middle East required an ELS to be developed and qualified specifically for their offshore well conditions. A new technology qualification program was devised in collaboration with the operator to qualify both the electronic and mechanical functionalities of the tool. This paper documents the methods and results of the extensive qualification test program. The development and qualification process were successfully completed within 10 months at research and development facilities in Norway. Following qualification testing, the ELS was first deployed for the operator in an offshore well in Q4 of 2019. Operational considerations in programming the remote functionality of the tool is presented in this paper. After a successful field trial, the ELS has been run in more than 15 offshore wells and has become the standard option in the operator's completion program.
{"title":"Remote Activated Completion Technology Enhances Operational Efficiency of Offshore Wells in Middle East","authors":"V. Keerthivasan, D. Young, Cathrine Mehus, Bjørnar Gjedrem, Moetaz Abdelghany, Henry Khov","doi":"10.2118/204867-ms","DOIUrl":"https://doi.org/10.2118/204867-ms","url":null,"abstract":"\u0000 To access a larger amount of pay zone, well trajectories are becoming longer and more complex, creating greater challenges for running completion liners. A liner shoe is a casing accessory tool that aids in the running of completion liners in long wells by allowing auto-filling of the liner and enabling pumping through the bottom of the liner. Upon reaching planned liner depth, the liner shoe is closed to allow for pressure testing and subsequent completion operations. Conventional methods used to close a liner shoe involve well intervention to set plugs or by dropping a ball, and there are inherent costs and risks associated with these operations. This paper presents the development and deployment of a remotely activated electronic liner shoe (ELS) for offshore applications that enables interventionless closing of the liner shoe, thereby improving operational efficiency, and reducing potential operational issues that could occur while closing the liner shoe conventionally. The ELS allows the operator to precisely control when the liner shoe closes – either based on pre-programmed pressure signals, a timer, or a combination of the two. A major operator in the Middle East required an ELS to be developed and qualified specifically for their offshore well conditions. A new technology qualification program was devised in collaboration with the operator to qualify both the electronic and mechanical functionalities of the tool.\u0000 This paper documents the methods and results of the extensive qualification test program. The development and qualification process were successfully completed within 10 months at research and development facilities in Norway. Following qualification testing, the ELS was first deployed for the operator in an offshore well in Q4 of 2019. Operational considerations in programming the remote functionality of the tool is presented in this paper. After a successful field trial, the ELS has been run in more than 15 offshore wells and has become the standard option in the operator's completion program.","PeriodicalId":11320,"journal":{"name":"Day 3 Tue, November 30, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90675543","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}
E. Barrera, Andrés Núñez, Kamal Atriby, Mauricio Corona, Mohamed AlMahroos, Arnott Evert Dorantes Garcia
In the Oil and Gas industry, there is a constant look for time and cost savings through performance enhancement and risk reduction. Not less important, wellbore quality becomes a crucial factor across target production intervals which enable safe and optimum completion operations in the well. While the techniques to drill wells constantly evolve, technology is advancing at faster pace every year. The application of new tools and digital technologies is the step change from progessive growth to exponential increase in performance. This paper contains a detailed description of a successful implementation of a combined integrated strategy, including the procedures established to maximize both; performance and wellbore quality in highly deviated and lateral horizontal sections in deep gas wells in a giant gas field in the Middle East. It describes the application of specific technologies that helped to improve wellbore quality and allowed corrections in Real Time.
{"title":"Pioneering Integrative Solution for Enhancing Wellbore Quality Thru the Application of Multiple Real Time Monitoring Services in Deviated and Lateral Sections in Deep Gas Wells","authors":"E. Barrera, Andrés Núñez, Kamal Atriby, Mauricio Corona, Mohamed AlMahroos, Arnott Evert Dorantes Garcia","doi":"10.2118/204790-ms","DOIUrl":"https://doi.org/10.2118/204790-ms","url":null,"abstract":"\u0000 In the Oil and Gas industry, there is a constant look for time and cost savings through performance enhancement and risk reduction. Not less important, wellbore quality becomes a crucial factor across target production intervals which enable safe and optimum completion operations in the well.\u0000 While the techniques to drill wells constantly evolve, technology is advancing at faster pace every year. The application of new tools and digital technologies is the step change from progessive growth to exponential increase in performance.\u0000 This paper contains a detailed description of a successful implementation of a combined integrated strategy, including the procedures established to maximize both; performance and wellbore quality in highly deviated and lateral horizontal sections in deep gas wells in a giant gas field in the Middle East. It describes the application of specific technologies that helped to improve wellbore quality and allowed corrections in Real Time.","PeriodicalId":11320,"journal":{"name":"Day 3 Tue, November 30, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90811385","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}
Mark Oatey, Fay Duff, Neil Emslie, Steven Christie, Rida Rikabi, P. Henderson, Kamaljeet Singh, Apoorva Kumar, G. Agrawal, Shaktim Dutta, Haroon Bajwa
In this paper, an end-to-end evaluation service using well historical production, petrophysics and reservoir data combined with new logs to perform well intervention solution methodology is followed. Across four wells, production logging data is acquired and analysed to understand the current performance of different heterogeneous layers. Combining this with openhole data, additional perforations and reperforations are planned. Perforations are carried out using deep-penetration charges to create a larger and deeper flow path between the reservoir and the wellbore. Post-perforation production logs are carried out, and the data is analysed to understand the effectiveness of newly perforated layers. Detailed production enhancement of all four wells is discussed in the paper. The majority of the wells displayed a significant increase in production when compared with pre-intervention flow rates. Minor scale buildup in the production liner was observed during pre-perforation production log data which was observed to be cleared during post-perforation production log data. The deliverability of the wells had also gone up, with similar production rates at much higher bottomhole pressure compared with pressures before intervention. This also confirmed the effectiveness of deep-penetration charges during perforation in providing better conduit from reservoir to wellbore. Additional perforations carried out, based on the heterogeneity of the reservoir and combining the openhole data, proved to be highly effective, with high deliverability observed from these new layers. In conclusion, a successful production enhancement of these low-flow-rate gas condensate wells was achieved with an end-to-end solution. A highly heterogeneous reservoir with multiple thinly bedded layers presented challenges in understanding their productivity. The combination of pre-perforation production log and post-perforation production log enabled evaluation of the deliverability of the complex heterogeneous reservoir. Further, production enhancement from each reperforated interval was confirmed using a direct measurement, i.e., production log data instead of relying on surface flow rates to better understand the downhole dynamics.
{"title":"Enhancing Production Through Well Interventions Using End-to-End Evaluation Methodology","authors":"Mark Oatey, Fay Duff, Neil Emslie, Steven Christie, Rida Rikabi, P. Henderson, Kamaljeet Singh, Apoorva Kumar, G. Agrawal, Shaktim Dutta, Haroon Bajwa","doi":"10.2118/204540-ms","DOIUrl":"https://doi.org/10.2118/204540-ms","url":null,"abstract":"\u0000 In this paper, an end-to-end evaluation service using well historical production, petrophysics and reservoir data combined with new logs to perform well intervention solution methodology is followed. Across four wells, production logging data is acquired and analysed to understand the current performance of different heterogeneous layers. Combining this with openhole data, additional perforations and reperforations are planned. Perforations are carried out using deep-penetration charges to create a larger and deeper flow path between the reservoir and the wellbore. Post-perforation production logs are carried out, and the data is analysed to understand the effectiveness of newly perforated layers.\u0000 Detailed production enhancement of all four wells is discussed in the paper. The majority of the wells displayed a significant increase in production when compared with pre-intervention flow rates. Minor scale buildup in the production liner was observed during pre-perforation production log data which was observed to be cleared during post-perforation production log data. The deliverability of the wells had also gone up, with similar production rates at much higher bottomhole pressure compared with pressures before intervention. This also confirmed the effectiveness of deep-penetration charges during perforation in providing better conduit from reservoir to wellbore. Additional perforations carried out, based on the heterogeneity of the reservoir and combining the openhole data, proved to be highly effective, with high deliverability observed from these new layers. In conclusion, a successful production enhancement of these low-flow-rate gas condensate wells was achieved with an end-to-end solution.\u0000 A highly heterogeneous reservoir with multiple thinly bedded layers presented challenges in understanding their productivity. The combination of pre-perforation production log and post-perforation production log enabled evaluation of the deliverability of the complex heterogeneous reservoir. Further, production enhancement from each reperforated interval was confirmed using a direct measurement, i.e., production log data instead of relying on surface flow rates to better understand the downhole dynamics.","PeriodicalId":11320,"journal":{"name":"Day 3 Tue, November 30, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-12-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75072124","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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