Day 1 Mon, November 11, 2019最新文献

{"title":"New Techniques for Metal Sulfate Scale Removal from Production Pipelines and Wellbore Case Study Sidi Kerir for Petrochemical Co.","authors":"M. Salah","doi":"10.2118/197252-ms","DOIUrl":"https://doi.org/10.2118/197252-ms","url":null,"abstract":"\u0000 This research present case study of sulphate scales found at water treatment unit, cooling water system and heat exchangers at Sidi Kerir Petrochemical Company Alexandria, Egypt, which declined overall production by 6%, about 250 million US. Dollar in losses 2018 due to unit's shutdown and flow restriction in pipelines. We tried many techniques like mechanical jet blasting using high-pressure water to crack the scale but it was a time-consuming root and need special equipment and large labour although it was not that efficient in areas with heat exposure and it cannot reach some areas. So we moved to next root for removing scales by chemical cleaning based on inorganic acid like hydrochloric acid, sulphuric acid,,, etc. although it can dissolve the scale in very limit efficiency but we didn't accept this method because those chemicals were very corrosive to metal surface like cast iron and stainless steel grade 304/316 also using those chemical present hard handling problem for adding or dilution. Therefore, we had to take the challenge to develop our new chemical cleaning methodology that combines between efficiency and safety. In new methodology, we developed new chemical formula based on mild organic acid mixture combined with sequencing agent, anti-re-deposition agent, wetting agent and pickling agent to chemically dissolve the scale in efficient and safe way.\u0000 The chemical cleaning technique was successful to dissolve the scale in very short time and in safe way to metal surface like cast iron and stainless steel. This invention is useful for the removal of sulphate scale like iron sulphate, calcium sulphate, barium sulphate and strontium sulphate from process equipment including pipes, pumps and storage tanks. It is also can be used to the removal of these scale deposits from other equipment such as boilers and heat exchangers.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"45 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85859699","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}

{"title":"Automated Sector Performance Review - A Collaborative Process to Identify, Interpret and Implement Profitable Opportunities","authors":"Muhammad Navaid Khan, Manal Al Bishr, R. Mohan, M. A. Marzouqi, L. Saputelli","doi":"10.2118/197500-ms","DOIUrl":"https://doi.org/10.2118/197500-ms","url":null,"abstract":"\u0000 The complexity of the recovery mechanism generally increases with the maturation of a producing field; therefore, the granularity of the reservoir analysis must increase proportionally to better understand the well and reservoir dynamics. ADNOC's Integrated Reservoir Management (IRM) Framework has instituted a set of workflows to focus on analyzing the reservoir performance at the sector level to assure reservoir performance sustainability. ADNOC has developed and implemented a robust automated Sector Performance Review (SPR) process using state-of-the-art analytics and business process management tool. The main objective of this work is to foster collaboration among multiple disciplines to assess the reservoir performance, as well as, to identify, interpret and implement profitable opportunities through a centralized platform (Al Marzouqi et al, 2017).\u0000 A unique process has been implemented in the five major assets of the ADNOC group, which covers approximately 50% of UAE overall production. The system leverages an automated integration of subsurface data from numerous sources; live analytics visualization provides reservoir performance insights on the sector level through automatically calculated KPIs and diagnostic trends. (Al Marzouqi et al, 2018). The integrated interface helps the multidisciplinary teams to identify the value-driven opportunities; the ranking and the feasibility analysis of these opportunities are governed by a closed-loop maturation process that involves the formal approval processes in order to obtain approval or authorization for action.\u0000 The solution offers an innovative way to establish collaboration among different assets to assimilate reservoir performance insights through a sustainable platform. Some of the immediate benefits include the effective execution of a reservoir management scheme, monitoring the variance between actual and anticipated performances during the course of projects, and assuring production target compliance whilst mitigating the shortfalls proactively. In fact, a reservoir level analysis tool (RPR) was piloted during 2017 and presented in SPE-193012-MS. However, with the necessity of having analysis at the sector level, the overall design of the solution is transformed to allow the users to carry out the analysis at sector and well level granularity. The SPR (Sector Performance Review) is enabling the achievement of a consistent approach across all assets for all subsurface performance review processes while improving efficiency through automation of data gathering and presentation and the identification of all underperforming reservoir, sectors, and wells.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"92 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83856936","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}

{"title":"Innovative Seismic Depth Imaging Workflow for Better Reservoir Understanding: TZ Offshore Abu Dhabi Case Study","authors":"Saif Ali Al Messabi, M. Mahgoub, F. Damianus, Babar Hasan, O. Khakimov, B. Tertrais","doi":"10.2118/197452-ms","DOIUrl":"https://doi.org/10.2118/197452-ms","url":null,"abstract":"\u0000 High fidelity seismic amplitude reconstruction through pre-stack migration is crucial for accurate elastic inversion. Despite a relatively flat geology of the Abu Dhabi region, accurate imaging is required for a stable elastic inversion. This can be challenging because the main reservoir Arab lies underneath the strongly anisotropic overburden of the Nahr Umr formation. In this case study, we show how we effectively addressed this challenge through PSDM.\u0000 With PSDM imaging, we have overcome the challenges of complex ray paths passing through the strongly anisotropic Nahr Umr layer and the rapid lateral velocity variation in the Mishrif formation. Evidently, the success of PSDM relies strongly on the accuracy of the depth velocity model used. To achieve this we adopt different forms of tomographic inversion, for example, using 3D non-linear slope tomographic inversion, where velocity and anisotropy (Epsilon) models are jointly inverted. Additionally, short wavelength velocity variations caused by the Mishrif interval are resolved through structurally-constrained tomography (SCT).\u0000 The superiority of PSDM imaging over PSTM in reconstructing AVA compliant seismic amplitudes is demonstrated on an ocean bottom survey from the transition zone offshore Abu Dhabi. Fast-track AVA elastic inversion is used to assess the benefit of PSDM imaging over PSTM. With a more stable Vp/Vs ratio and smaller inversion residual, PSDM imaging demonstrates a greater accuracy in reconstructing the pre-stack seismic amplitude and thus are more appropriate for estimating elastic reservoir properties.\u0000 The value of PSDM imaging for better understanding of reservoir characteristic has been well demonstrated in this case study from the Abu Dhabi transition zone, thus optimizing the value of the acquired seismic data for asset development.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"5 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77134293","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}

{"title":"CO2 Capture From Natural Gas Combined Cycle Power Generation Using Carbonate Fuel Cells","authors":"G. Kiss, T. Barckholtz, R. B. Gutierrez, Haiyang Lu, Brandon J. O'Neill, J. Rosen, Clay R. Sutton, E DavisKeith, J DobekFrank, C GearyTimothy, H. Ghezel-Ayagh, S. Jolly, C. Willman","doi":"10.2118/197377-ms","DOIUrl":"https://doi.org/10.2118/197377-ms","url":null,"abstract":"\u0000 Electrical power generation facilities account for a large share of global CO2 emissions. Because they are stationary single-point emitters, power plants are an obvious target for reducing anthropogenic CO2 emissions by CO2 capture. Capture from Natural Gas Combined Cycle (NGCC) power generation has been much less investigated than from coal power generation, despite having approximately half of the CO2 emissions per electrical unity of energy produced as compared to coal-fired power plants. Furthermore, the majority of carbon capture R&D has been devoted to the development of amine scrubbers, a process which incurs a significant energy debit because of its steam consumption in the sorbent regeneration step. Molten Carbonate Fuel Cells (MCFCs) can be used for CO2 capture from NGCC facilities without a significant energy debit. They are modular, thus flexible in fitting the required capture capacity. When using MCFCs for carbon capture, additional power is created by the fuel cells keeping the total efficiency of the power generation system at or near the efficiency of the NGCC plant without CO2 abatement.\u0000 This paper summarizes the current status of MCFC carbon capture technology for low-CO2 emission abatement. We developed modeling tools and performed process simulations to optimize MCFC performance and to develop and assess integrated solutions for power generation with carbon capture. We also obtained proof-of-principle data at the bench scale, using small button cells and lab-scale single cells. Additionally, we carried out process demonstration tests using pilot-scale fuel cell stacks. Our results indicate that the technology is feasible and effective.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"34 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87164799","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}

{"title":"Innovative Solution to Automatically Import Well Production Profile Data into Process Simulation","authors":"Eman W. Hassan, Giorgio Loretelli, H. Singh, F. Kamal, Ousama Takeidinne","doi":"10.2118/197623-ms","DOIUrl":"https://doi.org/10.2118/197623-ms","url":null,"abstract":"\u0000 EPC Contractors face the challenge of practicing/doing various activities that in most cases include some routine work (e.g. well characterization in Process simulation that requires extensive data entry, etc.). This routine work can be minimized by using developed automised solutions. These solutions will help to perform the above tasks as well as other tasks with higher efficiency and accuracy, less time and minimal errors while the Process Engineer will focus on more valuable tasks.\u0000 The Production Profile is one of the most important documents provided in any EPC stage since it is the basis for Process activities like simulations.\u0000 As per normal practice, the Process Engineer is requested to characterize each well in HYSYS using a no. of separation stages that depends on the project requirement. Well characterization includes finding the choke valve inlet flowrate and composition at the operating conditions using the productivity data. Productivity data includes the flowrates at Stock Tank Conditions and the reservoir composition. This task requires an extensive data entry since all wells have to be characterized for various production years. Moreover, any revision of such document may require an extensive re-work.\u0000 Performing Process simulations for an upstream project can be a challenging activity due to the possibility of having a high No. of wells that may need to be characterized in HYSYS. Moreover, the well characterization in HYSYS requires the input of oil/gas/water and gas lift productivity data in dedicated adjust blocks. For example, in a project having 100 wells and 4 governing cases, the No. of data that needs to be entered is 1200. This activity needs to be performed by the Process Engineer by reading the production profile and enter its data manually in HYSYS.\u0000 NPCC has developed a new software whose scope is to:Import the Production profile in a standard templateProvide a track change for any production profile revision.Provide the governing cases (Max. Oil/Gas/Water) and their relevant production years for individual wells/Flowlines/Trunklines/Pipelines as well as the overall production.Automatically export into HYSYS the production rates that need to be used for well characterization.\u0000 With the above software, the following benefits are achieved:Reduction in manhours.Increase in efficiency.Minimum supervision from Process Engineer is required.Reduction of mistakes/human errors.\u0000 This paper demonstrates that saving in manhours/manpower is achieved by interfacing EXCEL and HYSYS through VBA. Dedicated software has been coded to import the production profile provided during FEED/EPC stage in a more presentable and organized format that can be sourced to HYSYS. This will help in facilitating process simulations as well as achieving higher efficiency in Process activities.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"18 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86007388","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}

{"title":"The Impact of Dynamic Filtration on Formation Testing in Low Mobility Carbonate Formations. Case Study: Lower Cretaceous Carbonate Reservoir in the UAE","authors":"M. Kuliyev, S. Molua, K. Cig, S. Sepehri","doi":"10.2118/197221-ms","DOIUrl":"https://doi.org/10.2118/197221-ms","url":null,"abstract":"\u0000 Formation pressure and sampling measurements in low mobility formations under dynamic filtration can lead to measurements influenced by continuous mud circulation. Generally, active mud circulation inhibits mud cake growth, promoting filtration and invasion of mud filtrate into the reservoir. The resulting invasion adds its own pressure to the actual formation pressure. This is more pronounced in low mobility formations where pressure or sampling measurements made with mud circulation show higher than expected reservoir pressures and/or extended clean up times as a result of dynamic filtration and invasion.\u0000 We focus on formation pressure acquisition and present data sets where pressure acquisition was done with active mud circulation. The data is then compared with measurements acquired in a pseudo-static and static mud column.\u0000 The measured near wellbore formation pressures acquired with active mud filtration are significantly higher (in some cases, > 400psi) compared to those obtained with a static mud column (assumed to be reading closer to the true formation pressure). The additional pressure is often referred to as supercharging, i.e., the excess pressure superimposed on the original formation pressure by the viscous flow of mud filtrate. The difference depends amongst other factors primarily on the formation mobility and surface pump flow rate during the pressure acquisition. For higher mobilities, there is generally little appreciable difference between active mud circulation and zero mud circulation. Secondary factors like pipe movement, pipe diameter, mud composition and reservoir wettability also influence the degree of the extra pressure measured.\u0000 Best practices for formation testing while drilling in low mobility carbonates are discussed. Lessons are drawn from experience where ignoring such best practices result in questionable data.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"275 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73550933","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}

{"title":"Reducing Pipeline Maintenance Costs, Time, and Resources Through Nonintrusive Diagnostics","authors":"N. Stewart, G. Jack","doi":"10.2118/197262-ms","DOIUrl":"https://doi.org/10.2118/197262-ms","url":null,"abstract":"\u0000 Maintaining pipelines in optimum condition is a costly and time-consuming process for operators, which requires many resources. To help ensure an asset remains in a good operational state, it is necessary to understand its condition to allow it to be maintained in an efficient and cost-effective manner. Current methods for deposit assessment are limited to intrusive methods, theoretical modeling, or external measurement. This paper details a compressive solution to these challenges using pressure wave analysis.\u0000 The method is based on analyzing the signal response generated by a pressure wave transiting the system as it is affected by geometrical changes in the system. By capturing high resolution pressure measurement on an ultrahigh speed logger, the generated pressure wave can be recorded for analysis. Applying acoustic velocity gradient modeling in conjunction with the effect of the of the system and the fluid parameters, the profile of the internal bore of the system can be accurately determined without the use of intrusive or localized external tools.\u0000 Detailed is how the theory behind the method is confirmed by results observed when used during a controlled full-scale field-trial environment in addition to subsequent activities to survey system profiles. A case study is presented, demonstrating that the method allows operators to make decisive asset performance decisions and review deposit buildup in a safe and cost-effective manner without having to stop production. The theoretical method for calculation of acoustic velocity for known system and fluid parameters is shown to be accurate within tolerances compared to the acoustic velocity gained in the field by recording the time of flight between two known points. It is demonstrated that restrictions can be detected to a level of accuracy of plus or minus three millimeters of thickness, verified by comparison with other inspection methods.\u0000 The described is a unique method for determining the internal profile of systems, which can offer significant advantages from traditional bore determination methods. It can provide information in a repeatable and verified level of accuracy without the requirement for expensive and time consuming intrusive intervention, this allows operators the opportunity to target remediation work in the most efficient and cost effective manner, therefore maximizing production uptime and throughput.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"82 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85858174","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}

{"title":"Unlocking Challenges in Water Injection Development Schemes Utilizing a Novel IRM Automation Workflow for Opportunities Generation","authors":"A. Shbair, L. Saputelli, F. Noordin, V. Bogoslavets, Y. Alblooshi, A. Soufi, Mohammed Hijjawi","doi":"10.2118/197708-ms","DOIUrl":"https://doi.org/10.2118/197708-ms","url":null,"abstract":"\u0000 Water injection is by far the most popular method used in the secondary recovery phase of field development for oil displacement and pressure maintenance. Proactive reservoir management is important to validate the efficiency of the existing water injection schemes and to assess field development strategies to prolong oil production plateau and improve the recovery factor (RF). The main challenges arise in stretching the reservoir target whilst ensuring stabilized or reduced water cut (WCT), minimizing by-passed oil volumes and preventing wells from becoming inactive due to high WCT.\u0000 In order to mitigate premature water flooding issues, mainly two options are available: (1) artificial lift techniques to activate producers suffering early and rapid water breakthrough; and (2) optimized completion designs via preventive or corrective controls. Preventive (i.e. proactive) approach involves segmenting the wellbore using sliding sleeves, influx control equipment, limited-perforated liners, while corrective (i.e. reactive) methods attempt to divert/remedy unwanted water influx via water-shut off (WSO) interventions. None of these alternatives can be fully pursued as full-field development strategies without realizing the technical limitations as well as their economic benefits.\u0000 The objective of this paper is to determine the value of applying subsurface water control strategies in the context of enhancing reservoir management and develop a novel framework to assess potential remediation opportunities. The technical evaluation was supported by a robust Integrated Reservoir Management (IRM) process. This process identified the rig/rigless jobs opportunities to intervene inactive wells due to high WCT and rank all possible mitigation methods in an automated economic manner.\u0000 The findings have also proved the value of installing autonomous inflow control devices (AICDs) to control water production along horizontal sections. In effect, it controlled water slumping without jeopardizing oil production of wells awaiting gas lifting. A case scenario of combined Gas-lift and ICD deployments suggested a net incremental value of $66 million (or 106%). Field test results of the horizontal well's production and WCT were found to be within 10% of the expected planned rates, and the oil gain is expected to further improve by 50% when gas-lift is commenced.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"7 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88163455","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}

{"title":"Breaking New Grounds and Records for Unconventional Reservoirs Characterization Using the New Formation Testing and Sampling Technology","authors":"M. Kelkouli, John Zaggas, Y. Boudiba, Abderrahmane Akham, Riad Boumahrat, S. Ferraz, Sofiane Bellabiod","doi":"10.2118/197281-ms","DOIUrl":"https://doi.org/10.2118/197281-ms","url":null,"abstract":"\u0000 An exploration deep well crossing two reservoirs with different quality and properties, having an objective of: Fluid identification and sampling in extremely tight section (∼0.02mD/cP mobility) as well as in another section that is suspected to be depleted with very high overbalance exceeding legacy tools, knowing the hydrostatic pressure being ∼9500psia.\u0000 Wireline formation tester was run using single probe, leading to 65% of tight stations, the rest were valid but with very low mobility. This exposes the tool to an increasing pressure differential exceeding its physical limit and leading to damaging it. This makes any further analysis impossible. The toolstring was upgraded with latest technology of WFT, that is a merge between probe based and dual packer modules. This new technology was designed with extreme environments in mind, that allows sampling in all mobility range from extreme tight to very high with its capability of holding up to 8000psia differential pressure.\u0000 In the job described here, some of the tested reservoir sections were differentially depleted, something unknown to customer as this was an exploration environment. Since this information were not know even after the completion of the first and second run, a third run was carried out with the objective of re-investigating the same depths performed by the single probe, but this time 3D Radial Probe was used instead. This gave the advantage of taking the pressure down to almost 0 psia. The potential hydrocarbon zone which was bypassed (seen dry with single probe) was then tested with 3D radial probe giving a reservoir pressure of 2864psia with a mobility of ∼300mD/cP where gas condensate was identified and captured. Now for the extreme tight reservoir section, in combination with high hydrostatic, the mechanical limitation of traditional tools remains the same making sampling and/or fluid ID impossible. An attempt was made using the 3D radial probe, and despite the extreme low mobility ∼0.02mD/cP, an identification of the reservoir fluid (water) was successfully completed without any issue.\u0000 The use of 3D Radial Probe technology gave a completely different picture from what was expected, enabled the completion of all objectives and made the impossible (with conventional technology) possibly and easily achievable. This resulted in changing the well strategies accordingly and complete the well successfully. The new technology made the testing of unconventional reservoirs a reality.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"31 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83950867","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}

{"title":"Running Sour Hydrocarbon Assets: Eni's Story of Experience","authors":"L. Scataglini, L. Decarli","doi":"10.2118/197582-ms","DOIUrl":"https://doi.org/10.2118/197582-ms","url":null,"abstract":"\u0000 Eni has more than 40 years' experience on developing and managing sour hydrocarbons Projects. That has allowed to build up in Eni a specific knowhow, which is continuously improving and updating through operational activities on assets with an high concentration of H2S in the process fluids such as Karachaganak and Kashagan in Kazakhstan, COVA in Southern Italy and the more recent Zohr facilities in Egypt.\u0000 The Eni's acquired knowledge in running sour hydrocarbon assets, both offshore and onshore, has been founded on a robust risk based approach. Since the project start, risk assessments such as blowout study, Quantitative Risk Assessment, Emergency Escape Rescue Analysis, etc. results are considered the pillars for the proper design, construction, commissioning, start-up and operations phases. Specifically, SIMOPS/CONOPS methodologies and procedures and their applications in sour operational contexts are defined for managing sour hydrocarbons assets and activities.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"30 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78697268","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}