bluuebunny/crossref_metadata_2025_split huggingface dataset:
Integrated Downhole Multiphase Flowmeter and Autonomous Inflow Control Valve
Authors: Bjerke Anita , Aakre Haavard , Mathiesen Vidar 
Published: November 2019

Abstract
The Smart Autonomous Inflow Control Valve (S-AICV) technology is presented. This smart well sensor will prevent water and gas breakthrough and at the same time operate as a multiphase flow meter. The single compact system can be used in both mature and new field to map fluid flows along the well in oil reservoirs and at the same time autonomously controlling the production of unwanted fluid in the individual zones. This will provide the oil companies with detailed reservoir conditions data to have a better understanding of well production and drainage, and hence optimize future AICV well installations.
A multiphase flow model is developed which correlate the three pressures located inside the S-AICV (P1, P2 and P3) to flow rates of gas, water and oil going through the valve. At breakthrough of gas and/or water the S-AICV will detect pressure changes when the fluid composition changes. This model utilizes this pressure changes to distinguish between the different fluids and determine the flow rate and composition of inflowing fluid. The S-AICV application is designed for each specific field to achieve the desired functionality, and the user input parameters for this model need to be determined and individually adjusted accordingly to the fluid properties and the configuration of the valve.
This smart well sensor will extract data from the well and transfer the data to the surface via an optical fiber. The multiphase flow model will convert the signals to flow rates and composition, without compromising the autonomous and reliable AICV to meet the oil industry needs.
Existing measurement systems as tracers or various production logging tool are costly and complex. Separate multiphase flow meters can be installed in addition to the AICVs, but this is an expensive solution where only a fraction of the data can be gathered. The benefits of the S-AICV system are its ability to prevent water and gas production and at the same time continuously measure the flow rate and composition to register breakthrough within a low-cost package with maximizing data gathering.
An Integrated Approach to Tackling the Challenges of Drilling in a Highly Depleted Gas Reservoir
Authors: Zhang ZhongPeng , Wu Yan , Luo Lei , Wang Xueqin , Fan Yonghong , Yi Gang , Chen Chong , Zhao Fashou , Zhang Xiaoping , Liu Wei , Dong Hongwei 
Published: November 2019

Abstract
In many matured fields around the world, the infill well development faces multiple challenges; reservoir depletion caused by existing wells is unavoidable, the remaining area to be targeted by infill is typically relatively marginal, with thinner formations that still bear significant subsurface uncertainty compared with sweet spot area developed in the initial phase. In addition, some fields are impacted by PSC conditions, with a strict time constraint.
When developing infill wells several key aspects have to be considered: starting from potential severe mud losses, drill pipe stuck during the drilling phase, to formation damage, production interference with neighboring wells, earlier load up for gas wells etc.
Shell China developed an integrated approach by considering all these challenges, and successfully implemented it for the Changbei tight gas infill well project.
During the Design Phase, a series of core lab tests were carried out to evaluate the formation damage and related permeability reduction. The lab test results indicated that the permeability reduction as result of water encroaching into water wet rock formation is significant (+90%), causing a "water locking" effect. Another topic pertaining to the Desing phase in the Changbei field is the optimisation of the dual lateral well trajectory based on the expected depletion state of the reservoir. Also discussed is the horizontal well tubing size optimization, which accounted for the selection matrix based on KH, online date (related to PSC end) and expected reservoir pressure (depleted).
In the Delivery phase, the surfactant additive identified through the lab testing has been used into the drilling mud and completion fluid to appropriately mitigate the water locking effect. The lab test results demonstrated that a permeability improvement of at least 10% could be achieved. Furthermore, the surfactant concentration was optimized to maximise the emulsion effect for water treatment and the foaming effect during the drilling phase. This paper also covers the well flowback efficiency improvement achieved by additional nitrogen lifting and prolonged firing time.
During the Well Reservoir and Facility Management phase (WRFM), a study of infill well production interference with existing wells was carried out and the recovery could be maximized at the cluster level.
The Impact of PV Shades in Reducing Heat Stress in the ONG Drilling Industry in the Western Region of the United Arab Emirates
Authors: Siddique Abdul Hasib , Rodrigues Clarence , Simmons Rodney 
Published: November 2019

Abstract
Excessive heat in an oil/natural gas (ONG) drilling environment can have negative effects on workers, production levels and work efficiency. The United Arab Emirates (UAE) borders the Gulf of Oman and the Persian Gulf, and sits between Oman and Saudi Arabia. The summer temperature in the UAE can go as high as 51°C, which is extremely high for continuous outside work, especially considering that a 12-hour work shift is normal on the rigs. Due to global warming, average ambient temperatures in the summer are now generally higher than what have been experienced in the past. Although the differences are of only a few degrees, these small differences can make a big change in the work environment. Hence, companies have been trying to come up with engineering and administrative controls to reduce the effect of summer heat in this region. Photovoltaic (PV) array shades have been proposed in this paper to improve conditions for the worker. The Thermal Work Limit (TWL) has been evaluated in this study to understand the ability of PV shades in reducing thermal load on the body. TWLs have also been calculated without the shade and then compared against semi-indoor condition available on the rig. A model of PV shades has been designed to reduce the effect of heat stress keeping in mind the complexity of a rig move and other rig activities. Benefits of rooftop PV systems for area cooling are validated through previous studies and modeling. Heat flux modeling shows that solar panels can lower a roof's underside temperature by ~3°C. The PV array can also help in reducing heat loss during the cold winter nights. This paper also discusses the how this reduction of daily variability in surface temperatures under the PV shade helps to reduce worker's thermal stress.
Prevention of Well Control Incidents and Well Life Extension in Mature Fields
Authors: Yugay Andrey , Vorozhikhin Sergey , Daghmouni Hamdi , Al Shamsi Marwan , Yousef Abbas Ahmed , Abdelaziz Ahmed Saber 
Published: November 2019

Abstract
Well Integrity issues associated with barrier degradation due to corrosion could significantly impact on production results in mature fields. Sometimes those issues may lead to the severe well control incidents during production phase affecting on the performance of the facilities nearby. This paper describes the negative trend of well control incidents, which was changed, by using innovative approach of secondary barrier evaluation for wells with compromised primary barrier envelope. The objective is to share with the audience special practice of well integrity management using multiple barrier evaluation technology to prevent loss of pressure containment (LOPC) incidents. In addition, the method allows to extend the production life of wells with sustained annulus pressure (SAP) and continue operating those wells under specific conditions and periodic monitoring instead of immediate killing and securing. This "grace period" could be granted based on the known conditions of the secondary barrier envelope until the rig become available to fix the integrity issue and restore the well barriers.
Company started drilling activity in 1960's and since that time more than 4,000 wells have been drilled. All wells have carbon steel casings which serves as secondary barrier envelope in case primary barrier fail. Carbon steel easily gets corroded with time in case of insufficient protection and isolation from corrosive environment. Failure of both well barrier envelopes results in well control incidents. Uncontrolled release of hydrocarbons and other reservoir media to surface or aquifers has a strong negative HSE impact: it could be a reason for human injuries and deaths due to pressure, fire and H2S release, environment pollution, deferred production. Additionally, it is associated with unplanned increase in CAPEX and OPEX, reduction of business targets and KPI's, may cause negative impact on Company image and reputation.
Innovative proactive method of secondary well barrier evaluation, successfully used to prevent well control incidents, allows Operators to find the right balance between safety and operation, and extend the production life of the wells with integrity issues without jeopardizing safety and integrity conditions in the fields. Paper illustrates how 9 well control incidents have been prevented and 14 wells with compromised primary barrier envelope were allowed to operate for a limited period of time, until the integrity issues have been fixed.
Performance Enhancements through Mere Compliance with Air Filtration Standards
Authors: Rabia Hagar 
Published: November 2019

Abstract
This paper summarizes fuel gas consumption savings and enhanced efficiency benefits for operating Power Generation Gas Turbines. The cost savings and improved efficiency were achieved through the mere compliance with the latest air filtration standards.
European Standard for general ventilation air filters EN779 specifies fine filter class (F7 to F9) for filter element capturing particle sizes between 0.4-1.0 µm. Revised in 2012, a new requirement for Minimum Efficiency (ME) parameter was introduced for fine air filer classes. The new F9 filter elements replaced existing primary filters installed in a Power Generation Gas Turbine located in an ADNOC Gas Processing Site. Additionally, European Standard for high efficiency ventilation filters EN1822 revised in 2009 specifies filter element capturing particles at Most Penetrating Particle Sizes (MPPS). Efficiecy Particulate Air (EPA) - E12 filter class replaced existing high efficiency F9 filters. The upgrade also included replacement of D-Fog panels and primary filters' support mechanism with a new design.
To assess the potential benefits, a performance comparison study was carried out between two Gas Turbines. One Gas Turbine was upgraded with new air intake filters design; while the second was replaced with a new set of old filter elements. The new support mechanism for the primary filters eliminates dust bypass and filter looseness. The upgrade of existing D-Fog panels extends the life and maintainability. The new elements featuring Polypropylene fibres constructed in a 3D mesh can be washed and reused up to two times before replacement. Both Gas Turbines were started and operated for the same time interval. The study's results showed an increase in efficiency in terms of compressor isentropic efficiency and compressor polytropic efficiency at 2.14% and 1.61% respectively. An overall Gas Turbine efficiency increase of 0.35% was also realized. The fuel cost for 1MW generated was reduced by 0.39 USD/MWhr.
This tested and proven practical study is a testament to Gas Turbine users from all energy sectors across the globe. The verified financial gain and efficiency enhancements are great incentives for other Gas Turbine users to comply with the latest air filtration standards.
Predicting Mean Time to Failure in Horizontal Wells through Metal Loss Analysis and Produced Water Composition
Authors: Ofori Bruce Agyapong , Wei Mingzhen , Bai Baojun , Al-Kamil Ethar Hisham 
Published: November 2019

Abstract
Loss of well integrity in many horizontal wells in the United States has resulted in huge capital losses to several operating companies. The occurrence of corrosion in horizontal wells in the US is attributed to several reasons. The deposition of iron (Fe) and manganese (Mn) from manufactured steel pipe and the inability to effectively treat the laterals plays a major role in corrosion mitigation in horizontal wells. Corrosion inhibitors are injected into the wells to help reduce the corrosion rates, however the effectiveness of these injection applications is hampered by the types of well design and fluid dynamics. Loss of Fe/Mn in the lateral sections of the well is a major concern for the oil industry. This research will investigate the amounts of Fe/Mn contributions from the laterals and also investigate the relationship between iron and manganese counts from produced water from oil fields in the US. This research will further investigate the mean time to failure in the laterals and suggest proactive plans for mitigating failures based on findings.
High Fe/Mn concentrations could lead to corrosion in producing wells. High densities of Fe/Mn found in produced water analysis reports has been attributed to the abundance of these two elements used in manufactured steel pipe. These elements are used due to their abundance in manufactured steel pipe and their lack of natural presence in formation fluids. Fe and Mn have a known ratio in steel pipe of approximately 100:1 (depending on steel type). These high concentrations could ultimately compromise the wells integrity.
This research emphasizes the need for considering iron and manganese counts as integral part of the corrosion monitoring. Moreover, considering the long lateral casings, which spans several thousands of feet in the US, injection of corrosion inhibitors will be ineffective in reducing Fe and Mn loss in the lateral sections. Monitoring of Fe and Mn over such long laterals is challenging and costly. It has therefore become crucial for oil companies to thoroughly understand the Fe/Mn contribution from the laterals that could lead to corrosion and develop mitigation strategies to lower corrosion rates in such high-risk wells. This will help to implement remedial measures to better define corrosion rates and quantify the risk of failure. This will also enable oil companies allocate resources for further development and not several remediation efforts.
Condition Based Maintenance for Oil and Gas Industry Based on Data Reconciliation Techniques
Authors: Craciun Ionel , Lecoq Frederic , Digavalli Suryaprakash 
Published: November 2019

Abstract
This article proposes a new approach for dealing with maintenance issues for large industrial processes. The case study is taken from an industrial implementation of a condition-based maintenance project for the heat exchangers from the crude preheating train of a European refinery. The application was developed based reconciled data using the advanced data validation and reconciliation tool, VALI, developed by Belsim.
The article proposes the riguroous calculation and monitoring of the fouling factors of heat exchangers as crucial parameter to alert the operator about the condition of the heat exchangers. The calculation of fouling factors is performed automatically by the application with a minimum initial input effort from the part of the modeler: design date for film transfer coefficients for the both sides of the heat exchanger. Industrial data shows that the heat exchangers from the crude preheating train are prone to relatively quick fouling. The financial analysis of the impact of the fouling problem on the normalized daily fuel consumption in the crude furnace has shown that the high initial financial gain of a preheater cleaning can amount to as much as 20% of daily fuel cost. However, the performance degradation sets in very fast and the high initial gains are not sustained for prolonged periods of time. On the other hand, the overall performance degradation slows down in time and the performance of the crude preheating train stabilizes at lower values, making the decision process for heat exchanger cleaning more difficult in situations of pressures to maintain production volumes.
Identify and Recommend High-Value Improvement Opportunities in a Geologically Challenging Reservoir
Authors: Al Dhanhani Helal , Fazal Ayub , Selvam Balakrishnan , Obeta Chukwudi , Herrmann Rolf , Kosik Ivan John 
Published: November 2019

Abstract
This abstract proposes an optimum plan for offshore Abu Dhabi carbonate reservoir capitalizing on all historic and ongoing lessons learned and defining clear actions, pilots and completion technologies to achieve and sustain desired production target. Different completion designs will be discussed in this paper to define the optimum completion strategy per well and area.
The completion designs were as follows: Single completion with 10000ft (10k') lateral lengthTri lateral with 10k’ branch (total 30k')Fishbone with 6×6k’ branches (total 18k')
Long standing strategy to develop this reservoir with line drive depletion. The base plan is to drill a single lateral with 10k’ lateral length and 1 km spacing with a plan to convert the base producer to an injector while the line drive spacing is downsized to 500m. The total footage of reservoir contact in this case is 10K’ in base case followed by 20K’ in the infill timing. The other completion designs are suggested to increase the reservoir contact at initial times to reduce the pressure drawdown in the production wells. Fishbone consists of a cemented motherhole with 6 branches 3K’ laterals at 30° angle (total footage ~18K'). Another completion design is the tri-lateral which consists of three branches parrelel to each other with reservoir contact ~30K'. The conversion strategy is not possible by the application of multilateral production wells due to the wellbore collision concern with infill drilling adjacent to multilateral wells. Note that branches in the fishbone and tri-lateral well designs are left as open hole due to liner access concern. For production performance comparison, due to well management logic of the model it was necessary to normalize the individual well profiles to attain an equivalent online date and equivalent amount of production days. The objective of normalization was to provide a fair and unbiased comparison of the competing completion types.
Calculation of the net present value (NPV) and comparing it for each well while taking into consideration the cumulative oil recovery results in a hybrid development scenario with preferred multilateral and preferred Monobore development wells. The dynamic model results were used to compare well by well the cum recovery and the NPV, which led to create an economical development scenario without jeopardizing the ultimate recovery.
A Distinctive Approach to Performance Measurement of a Digital Transformation Programme in an Energy Company
Authors: Talamonti Marco , Siciliano Lorenzo 
Published: November 2019

Abstract
The digital transformation in the energy sector has specific features arising from the characteristics of the sector, the dimensions of the assets and the complexity of the technologies and processes utilized in the research, production, transformation, and transportation and sale of energy to the end-user.
This paper describes the performance model developed in Eni to measure the success of the digital transformation programme. A top-down approach was developed for the three main sectors/areas impacted by the transformation i.e. the Industrial and Commercial sectors and the Support Functions area.
The model is structured in 3 layers: Strategic Goals, Company Results and Business Lines / Assets Operational Performances. For each layer, different sets of KPIs have been identified to measure the contribution provided to the Company's targets both operational and economic, from the digital transformation programme. Those KPIs are also complemented with indicators to monitor the progress of the on-going initiatives/projects and of the Change Management programme. Some preliminary results and next steps are also discussed.
Characteristics of IX1 Digital Acquisition System
Authors: Li Zhengzheng , Yan Wei , Huang Lei , Xia Ying , Yang Maojun 
Published: November 2019

Abstract
Oil companies has spent decades in pursuit of obtaining high quality seismic data at lower cost. Until recent years, with the development of the geophysical theories, oil companies have shifted focus to low frequency seismic data while keeping the advantages of large number channel operations. The conventional geophones, due to the restriction of working principles, don't have good low frequency response. And, it usually costs more for geophysical companies to purchase large number instruments. The iX1 digital acquisition system is designated to offer fundamental improvement for seismic prospecting, acquiring high-resolution seismic data at economic prices. This article describes the characteristics of iX1 digital system, ground equipment and digital sensor AccuSeis SL11.
Mature Oilfield Production Surveillance and Optimization Using Clamp-On Sonarflow Surveillance
Authors: Hussein Ahmed , Alqassab Mohammed , Atef Hazem , Sirdhar Siddesh , Alajmi Salem Abdullah , Aldeyain Khaled Waleed , Hassan Mohamed Farouk , Goel Harrish Kumar 
Published: November 2019

Abstract
Umm Gudair (UG) field is one of the major oil fields of West Kuwait asset. Wells are tested periodically using multiple conventional test separators and data is subsequently used to update Well Performance "Nodal analysis" and "Live Flow Line Surface Network Model".
A different approach was tested in 2018 for a mature oil field in the Middle East to evaluate the effectiveness of Clamp-On based SONAR Flow Surveillance solution against existing conventional portable test separator. The objective was to check the performance of the SONAR Flow Surveillance on black oil wells at different flowing conditions, and ultimately implement a new approach to increase the testing frequency, reduce any potential of hydrocarbon release, avoid well shutdown, optimize operating costs, and production optimization.
The SONAR Surveillance approach is based on SONAR clamp-on flow meters deployed in conjunction with compositional (PVT) and multiphase flow models for oil and gas wells to interpret the measurements of the SONAR flow meters at line conditions (pressure, temperature, fluid stream composition), and output the gas, oil and water phase flow rates at both actual and standard conditions. The SONAR meter measures the bulk flow velocity (at line conditions), then a flow computer determines the individual phase volume fractions at actual conditions using a PVT model and water-cut. This provides a measure of the oil rate at actual conditions. A shrinkage factor calculated by the black oil model is applied to report oil rate at standard conditions. Gas and water are also inferred in a similar manner. The gas, oil and water flow rates thus determined at actual conditions are further processed and converted to standard conditions as well.
The field tests showed that the SONAR Flow Surveillance approach allowed more flexibility in terms of field installation and the measurements are made at actual production conditions unlike other devices that may introduce additional flow restrictions. The SONAR meters diagnostics also provided a more realistic representation of the well flow profile since the measurements are instantaneous versus the "averaging" effects observed when using gravity-based separators. This allows better production surveillance and understanding of changes in well behavior.