bluuebunny/crossref_metadata_2025_split huggingface dataset:
Sustainability Driven Produced Water Treatment Technology Solution at Nano-Scale
Authors: Myo Thant Maung Maung , Che Daud M Faizal , Shaffee Siti Nur Amira , Sedaralit M Faizal 
Published: October 2022

Abstract
Treatment and disposal costs of produced water from oil and gas operations remain the primary concern with the ongoing global push toward the transition to cleaner energy and Zero Liquid Discharge (ZLD). Gas floatation utilizing micro-size bubbles is commonly used in produced water treatment. However micro-size bubbles are not effective in removing dissolved oil (such as Benzene, Toluene, Ethyl-benzene, and Xylene) and usually require chemical pre-treatment to remove the emulsified oil. This paper aims to present the challenges, and lessons learned from produced water treatment technologies as well as recent technology development in nano-bubble floatation technology with a concept select study of pilot deployment at one of the terminals in Malaysia.
First, state-of-the-art analysis of existing gas floatation technology to treat produced water is presented. From the analysis, the failures and lesson-learned from the technology implementations are identified. To improve the efficiency of gas floatation technology, the effects of reducing the micro-sized bubble to a nano-sized bubble, bubble concentration, and type of gas have been evaluated. Subsequently, several improvements are developed and tested to overcome existing gas floatation technology. The pilot application of this developed technology at one of the crude oil terminals in Malaysia, which include a feasibility study, concept selection and engineering of this technology is described as a case study.
The typical gas floatation system is much less efficient in produced water where dissolved oil fraction is high and, in the presence of the fines solid. As a result, the required oil in water separation is not met leading to disposal limit compliance issues and the poor recovery of hydrocarbon in produced water. Changing operating envelope over time i.e., reduced production, increased water cut, and fines sand production, affects gas floatation efficiency over time. It is also not cost-effective to produce large volumes of microbubbles that are smaller than oil droplets. From our analysis, a significant improvement in oil-in-water (OIW) removal is achieved by controlling the bubble size, gas type, and bubble concentrations via a nano-bubble floatation unit. This technology successfully maintains the less than 10ppm OIW target removal and a further reduction in the required treatment stages and chemical consumption. The system is a promising technology for brown and green facilities, wet or dry terminals, or even for downhole applications to increase oil recovery.
New design elements are proposed to increase separation efficiency under erratic multiphase-flow conditions, increased water cuts, and the presence of fine particles. Testing results of the compact, low-energy, high reliable nanoscale gas floatation system are presented and are a promising technology for both aging and new facilities.
Leverage Telemetry Scada and Machine Learning on Pumpjack Wellhead Production Facilities
Authors: Susanto Tedy 
Published: October 2022

Abstract
The purpose of the installed Rod Pump Controller system was to demonstrate production optimization and OPEX reduction, with the aid of Machine Learning and AI based application that helped Operators and Petroleum Engineers better manage the wells. Another one was to help customer evaluate the "as-a-Service" payment model to operate the wells. Such payment models are becoming more relevant across the industry, where International or National Oil Companies allows technology vendors to manage the entire Electrical and Automation scope for wellhead monitoring and optimization. Several issues can develop with this application that can create costly repair situations. Traditionally these have been monitored by personnel visiting each unit on a prescribed basis to ensure they are still operating and then making adjustments during the visit. This makes it ideal for monitored control to ensure maximum liquid production and reduced operational costs. Production optimization for rod pumps is best accomplished by regulating the speed of the pumpjack as reservoir levels rise and fall, in order to gain maximum production without over pumping the well and damaging the equipment. Better management of motor speed can also provide power savings for the end user.
Edge computing is the concept of pushing applications, data, and computing power away from centralized points to the logical extremes of a network. In the oil and gas field, this would be the rod pump well sites. Edge analytics is enabled through a combination of Machine Learning and Control Room/Cloud learning for model development. This approach takes advantage of the unlimited processing power and abundance of historical data available in the control/server room. The model is executed in real-time in the Edge minimizing lag and providing real-time feedback and insights to the operations and productions teams.
As part of the project, it was able to demonstrate an end-to-end cyber secure architecture for the rod pump analytics application. The software platform, inclusive of the Edge gateway and the cloud solution, collected all generated dynacards from the RTU and predicted dynacard shape for every stroke. By doing so, the software provided real-time analytics of rod pump performance along with production and energy consumption parameters. Finally, the benefit of the solution are make better production optimization, cost reduction and improve production revenue/uptime, reduce well service down time. Hence all these things will reduce CO2 emission and drive sustainability strategy for customer.
Innovative Online ESD Valve Seat Leak Detection Technique Using AE & AI Embedded Methodology in Optimizing Cost/Time & Maintain Plant Integrity
Authors: AlSulaimani Aysha Mubarak , Majumdar Pradip , AlHammadi Badhria 
Published: October 2022

Abstract
More than 1000 emergency shutdown valves are installed in the gas processing facility in different applications such as battery limit isolation, equipment isolation, unit/train isolation, pressurization/depressurization of section/unit as per different shutdown level.
There are four main categories of ESD valves considered; i. Emergency Service (ESDV & EBDV), ii. Inventory Isolation, iii. Pipeline Sectioning/Isolation and iv. Process Service (Routing, Sequencing, etc.)
Agile Field Development Study Leveraging Fast-Tracked Reservoir Modeling and Data Analytics While Incorporating Reservoir Uncertainties
Authors: Al Lawati Husain Ali , Al Hashmi Salim Musalam , Al Harthy Nabil , Ahmed Ahmed Fadhl Mustafa , Fletcher Kathryn Joanna Clark , Shergill Galvin Singh , Zahid Salman , Ahmad Ammar , Hameed Omair , Shahid Shawwal , Al Bahrani Mundhir , Al Kindi Zainab 
Published: October 2022

Abstract
A small onshore brownfield in south Oman has low oil recovery because of its heavy oil and high water production, which together with reservoir uncertainties poses development challenges. Petrogas implemented an innovative field development planning approach to quantitatively compare multiple field development scenarios and optimize the operational choices within each.
The workflow started with a single history matched model for each of the two geological structures in the field. A set of 14 field development scenarios were defined, on injection rates, well locations, and injection fluids. Identification and quantification of subsurface uncertainties were performed. These uncertainties were included in the geomodel for each scenario, which generated an ensemble of realizations and corresponding production forecasts. Two sets of economic results were produced—a simple, discounted cashflow model and the fiscal terms of the operator's service contract. Each ensemble was run against these models to generate probabilistic performance indicators for each scenario.
Using cloud-computing capability, the field development study was drastically accelerated without losing on the quality. Almost 800 simulations were run over 5 days, covering 32 development scenarios in total (for two structures), automatically integrated with the economics workflow, providing in-depth analyses. The scenarios were compared in a series of dashboards that presented the economic metrics and their corresponding cumulative distribution functions.
The analysis yielded several important insights: longer wells did not provide enough additional production to offset the increased costs. Moreover, peripheral drive with horizontal wells was more effective than irregular vertical wells. The waterflood scenarios improved production, but the polymer-injection option with short horizontal wells and peripheral infill well pattern was the highest-performing scenario. The study also helped identify areas where more detailed optimization studies should be performed, e.g., to optimize polymer-injection scheduling and polymer design.
Traditionally, subsurface uncertainties analysis was restricted to a small number of discrete model realizations. Results were quantified in terms of production ranges only. Here, production forecasts were based on an ensemble of models, capturing the full range of uncertainties. In addition, evaluation criteria included economics.
Avoiding Plant Shutdowns Through Extension of Temporary Clamps Life Time by Engineered Over Enclosures
Authors: Al Khoujah Khaled M Mazen , Frost Liam , Al Qaydi Juma Rashid , Al Blooshi Saeed , Al Mansoori Fatima Hassan , Evgeny Shakirov 
Published: October 2022

Abstract
ADNOC Sour Gas's Plant has been in operation for 6 years and throughout that period, similar to other operating plants, various piping, flanges, and valves leaks were identified; Some of the leaks cannot be attended online and requires a plant shutdown to perform permanent and long term repair activities, and hence, conventional leak sealing clamps were used to restrict the leakage. However, due to short life span and tight expiry period of these clamps, new enclosures were designed so that can extend the expiry up to 5 years. Thus, avoiding Total and/ or partial plant shutdowns to replace the clamps with a permanent solution. This paper will present an implementation of the Leak Sealing Enclosures, so called, clamps over clamps and will discuss its design factors and basis.
This paper will present a breakthrough innovative implementation of Engineered Enclosures over failed and expired leak sealing clamps, to extend the life of the clamps, and hence, ensure extended safe and sustainable production and operations. Leak sealing clamps are common to be used as temporary repairs over leaking pipes, flanges and valves when permanent repair is not possible in operational oil and gas plant on leaking pipe.
Centralized Predictive Analytics & Diagnostics Value Creation
Authors: AlSulaimani Aysha Mubarak , Majumdar Pradip , AlHammadi Reem , AlHammadi Badhria 
Published: October 2022

Abstract
The implemented maintenance strategy for rotating equipment in the field was conventional time-based (6months-1year) maintenance. Due to this maintenance philosophy, many equipment's were serviced every 6-12 months including the stand-by equipment. Thus, material, spare parts and man-hours are consumed very frequently. In 2019, company decided to convert the maintenance philosophy from time-based to running-hours based and based on OEMs recommendations, 4000 running-hours was the optimum running-hours before the equipment maintenance. By implementing this technique, the frequency of equipment maintenance was reduced and thus maintenance cost and service cost were reduced as well. Moving towards the deployment of AI technology and digitalization world, a new requirement to deploy predictive maintenance analytics and tools elevated. The Centralized Predictive Analytics & Diagnostic (CPAD) which is a centralized ret time predictive monitoring solution for critical assets. The asset specific real time data from site historian will be replicated a centralized historian to enable continuous monitoring of these assets and failure predictions. The CPAD modules get these data streams and execute performance calculations for each asset based on first principle models and also monitor for the failure predictions through data driven models using APR methods. CPAD will generate fault notifications that will be transmitted to site experts for follow-up. CPAD project will be implemented in multiple phases. The first phase will be a pilot implementation as prove of concept and will include the deployment, commissioning and monitoring of all core applications. Once pilot prove of concept implementation schussed, it will to be followed by further implementation of remaining critical rotating equipment. The deployment of predictive maintenance and analytic diagnostics solutions will add value in different forms. It will support shutdown deferrals and planning for critical equipment, it will help in reducing maintenance cost of material, consumables, spares & man hour. In addition, it will help in the transition from preventive maintenance to proactive/predictive maintenance. Furthermore, the predication ability will help in early prediction and identification of potential failures and gives advisory recommendations to support rectifications of failures before the actual failure occur.
The pilot implementation started in 2020 with the deployment of 54 critical rotating equipment. The cases reported in phase-1 pilot implementation reported around $3.000.000 savings and proved the CPAD concept. A plan were put in place to capture additional assets in the CPAD system. Additional 108 equipment were deployed in phase-3 implementation of the project.
Production Optimization and Reservoir Monitoring Through Virtual Flow Metering
Authors: Maheshwari Nitin , Lobari Sultan , Saary Ali Awadh 
Published: October 2022

Abstract
Development of marginal oil fields having limited production rate are typically very challenging, especially for the fields where reservoir behavior could be very sensitive to the operating envelop. Also, minimizing the operational expenses is the key for economic development of such marginal fields. Bu Haseer is one of the marginal fields in offshore concession area of Al Yasat Petroleum Operations Company. Al Yasat has implemented hybrid virtual flow meter solution in Bu Haseer field, to enhance the reservoir management plan while minimizing the operational expenses.
Hybrid virtual flowmeter solution adopted by Al Yasat utilizes first principle based high fidelity multi-phase flow assurance simulator, leveraging its machine learning model for fast and robust flow estimation. Dynamic analysis and data driven approach of the virtual flow meter solution ensures the estimation accuracy and would highlight the system failure, if any. Utilizing available real time data from field, the virtual flow meter estimates the real time oil, water and gas flow rates from producers and expected down-hole parameters, within accuracy acceptable for reservoir surveillance and production optimization.
Typically, well performance is being monitored through periodic well tests and downhole monitoring through wireline activities. Frequency of such reservoir surveillance activities could be significant, especially for marginal fields due to reservoir sensitivity. Continuous real time reservoir monitoring through virtual flow meter provides better understanding of reservoir for timely corrective actions and maximizes the oil recovery in the field lifecycle. With the implementation of virtual flow metering technology, physical well testing and downhole monitoring will be limited for periodic validation and calibration of the virtual flow meter. Therefore, operational expenses for reservoir monitoring activities and associated HSE risks are also significantly optimized.
Virtual flow measurement using conventional steady state principles of physics is widely used in oil and gas industry. However, advancing the conventional methodology with a combined machine learning & dynamic simulation approach not only enhances the measurement accuracies, but allows the solution to be a tool for analyzing and identifying potential failures and their root causes. This paper presents Al Yasat experience in hybrid virtual flow measurement technology implemented in one of its marginal fields.
Brownfield Performance Data Driven Analysis and Integration with Urban Planning to Generate Field Development Plan in a North Kuwait Multi-Stacked Giant Reservoir
Authors: AlAbbas Reem , Majhi Somnath , Mishra Rajendra , Jha Manish Kumar , Abu Shiekah Issa , de Bruijn Gerbert , Vann Jeffrey 
Published: October 2022

Abstract
A mature and congested field with multi-stacked sandstone reservoirs has been developed through depletion drive for 50 years and more recently with peripheral water injection. Currently, the field performance shows rising water-cut in some reservoir units and pressure depletion in others, but still has significant remaining development potential. A field development plan has been established to economically produce bypassed oil, driven by the analysis of the historical performance data for the different reservoir units.
Integrated analysis of historical data and development decisions identified the subsurface and operational drivers behind the increased water-cut and differential pressure depletion. This paved way for developing clear recommendations for the major development decisions on well and completion type, well spacing and waterflood strategy. Oil production type curves generated for each reservoir unit using recent infill drilling historical production data helped establish the preferred development phasing and production forecasts. Urban planning is a key enabler to realize value from the future development of the field due to surface congestion; therefore, the new wells have been allocated to multi well pads.
The detailed analysis focused on each area of the field, complemented with saturation logs and dynamic model, helped in determining the long-term well requirements and their locations targeting bypassed oil. The integrated study generated a rolling development plan covering the field life cycle to accelerate oil production and reserves maturation and improve the reservoir pressure and sweep. Each new well has been assigned a primary reservoir target and a confidence level for the target reservoir to enable phased implementation of structured infill drilling to reduce well spacing starting with high confidence wells. New water injectors were added to the reservoir units that have limited aquifer support. Integration of the well pad allocation and development schedule with the pad construction schedule helped identify and mitigate against any surface related showstoppers to the planned well locations and the development schedule. As a result, more than 130 new development wells were added to accelerate oil production and increase production rates.
This integrated study manifests the power, efficiency and value from brownfield data driven analysis to capture lessons learned from evolving wells and development concepts applied in a complex field over six decades. The workflow enabled the delivery of an updated field development plan and production forecasts within a year through utilizing data analytics to compensate for the recognized limitations of subsurface models. Urban planning and multi-well pad drilling concepts alleviate the impact of drilling constraints.
WRFM Excellence in Fahud, Sultanate of Oman
Authors: Al Waheibi Hamed , Habib Ahmed , Al Shibli Abdullah , Al Saadi Hamoud , Al Mabsali Salima , Awlad Wadair Aamir , Yahmad’I Salim 
Published: October 2022

Abstract
The paper describes the best practices and the excellence of Well-Reservoir-Facility Management (WRFM) of one of the Oil Assets located in the North Salt Basin in Sultanate of Oman. The asset consists of 3 main oil fields. These fields have highly multi layered fractured carbonate reservoirs and have been mainly producing under Gas-Oil-Gravity-Drainage (GOGD) recovery process over the last 5 decades. The surface facilities consist of 6 gathering & processing stations, 23 High pressure gas compressors and 12 low pressure gas blowers. Besides the complex reservoirs, there are other two main challenges; first is the aging wells and facilities and the second one is the facilities gas and water handling constraints.
An integrated Well-Reservoir-Facility Management (WRFM) Framework was developed to maximize Lifecyle value and meet or exceed production, reserves, and cost targets despite the pertaining challenges. The framework outlines WRFM strategy, operational philosophy, Gap-to-Potential (GtP) plan, key uncertainties coupled with surveillance plan, key risks coupled with new technologies plan, budget planning and control, resources & capabilities, workflows & decisions. All of these were managed using the Continuous Improvement Fundamentals (CIF).
The WRFM practices and approach followed in the Asset under study has resulted in remarkable achievements in different fronts. Well integrity compliance is maintained above target. Well production optimization gain reached 4% of base production and plan in place to reach of 12% in the next few years which is above industry TQ of 10%. The optimisation jobs are very attractive at average UTC of 3$/bbl. The operating cost per well is the cheapest across the North Assets. The unscheduled oil deferment reached less than TQ of 2% of IPSC. The gas compressors availability reached 95% exceeding target of 92%. The flare has been reduced by more than 30%. The case study describes a novel approach on how to manage a complex brown field with ageing wells and constrained facilities.