bluuebunny/crossref_metadata_2025_split huggingface dataset:
Gas Processing Facility Energy Efficiency in Action Success Stories
Authors: AlMethn Abdulrahman , AlFawzan Mohammed 
Published: February 2022

Abstract
This abstract is prepared to share Haradh Gas Plant Department (HdGPD) processing facility Energy Management program tools and success stories, in line with the Saudi Aramco Energy Management Program Transition Strategy that developed, established and was tasked to minimize energy and environment-related impacts and improve energy performance through preset KPIs. This paper sheds light on the implemented and deployed programs; and innovative, in-house energy initiatives to optimize overall energy consumption.
The facility Energy Management System (EnMS) is fully aligned and connected to the corporate energy programs and it is part of the facility sustainability success factors. The facility implemented effective and mature Energy Efficiency Program over a seven-year cycle from the incubation in 2012 up to the current year. The facility has implemented a number of enhancement efforts innovative energy initiatives — to optimize fuel, electrical power, flaring/GHG emissions and water consumption, while meeting local customers demand — that include the Granted Patent for Fuel Purge Gas Optimization, Load Management Program, New technologies Adaption and Biodiversity Park Inauguration.
The program demonstrated sustainable Energy Efficiency Performance, which improved the overall Energy Intensity Index by more than 11.5 % below the baseline. This improvement was achieved in a sustainable approach that resulted in an energy saving of more than 15,848,300 barrels of oil equivalent through the years. The following are some realized benefits of the effective implementation of the energy management system tools: 〉Maintained fully functioning energy management systems and programs〉Maintained compliance with energy standards, requirements and regulations〉Qualified the facility to be an ISO 50001 certified during 2019.〉Recognized HdGPD as one of the best performers by winning several energy related awards, such as the "2018 President Environmental Excellence Award for Greenhouse Gases and 2019 International Green World Award" as well as the 2021 Environmental Excellence Award winner by GPA Midstream.
Waste Management Control by Applying Novel Method for HPLC Technique to Replace SKALAR Cadmium Reduction Method for Nitrate and Nitrite in Water Analysis
Authors: AlOudah Yahya 
Published: February 2022

Abstract
A new method was developed on High Performance Liquid Chromatography (HPLC) instrument equipped with a Photodiode Array UV detector to determine the Nitrite-Nitrogen and Nitrate-Nitrogen in seawater, industrial wastewater, and groundwater at very low concentrations. This HPLC used a reverse phase system with polar mobile phase and nonpolar C-18 Column. The split mechanism of the HPLC Chromatography was accomplished by employing acetonitrile and acidified water with pH 2.5, at 55:45 ACN: H2O v/v as a mobile phase, long HPLC Column (C-18, 0.5 μm, 250 × 4.6 mm) and at 1 mL/min flow rate. The calibration curves of nitrate-nitrogen and nitrite-nitrogen in the range of 0.05 to 1.0 mg/L were exceptionally linear with correlation coefficients greater than 0.999 and with low Method Detection Limit (MDL) of 0.02 mg/L for both of NO2-n and NO3-n. This developed method also showed comparable results to the ones obtained by the traditional SKALAR instrument which follows ASTM D3867 Automated Cadmium Reduction Method. The results of the nitrate-n and nitrite-n for the Quality Control Samples (QCS) and the average recoveries percentage of the spiked samples demonstrated high accuracy values 99.20% - 101.40% & 98.4% - 99.1% respectively. The very low detection limit is what set this study apart from the previous conducted studies on nitrate and nitrite determination by HPLC. This new developed method is safer and with minimal cost compared to the traditional cadmium reduction method. It doesn't consume water, or require preparation of many hazardous reagents that contain and generate cadmium wastes.
Reducing Fugitive Emissions from Control Valves
Authors: Daniels Kyle , Catron Frederick , LeBoeuf Catherine 
Published: February 2022

Abstract
Dilating Disk control valves were installed in a refinery to monitor their performance from a process control and fugitive emissions standpoint. By using a patented stem sealing system, the stem seal is capable of reducing fugitive emissions from the valve stem down to 0 ppm. This claim was to be evaluated in the field under application conditions in accordance with the methodology reported in EPA Method 21 and UNI EN 1544 standard.
The Dilating Disk control valves were allowed to run in service for approximately 9 months before fugitive emissions testing was conducted. During the 9 months of run time, and prior to the fugitive emissions testing, the valves were monitored for how well they controlled the flow rate, reacted to control room signals, were positioned at the correct percent open, and provided the correct pressure drop. After the 9 months of run time, and experiencing no operational issues, the fugitive emissions testing was scheduled.
This project was conducted at an Eni refinery in Italy, the group within Eni, Eniprogetti, performed a monitoring activity focused on evaluating and measuring possible fugitive emissions from five valves installed in Feb 2020.
The fugitive emissions were measured by the Eniprogetti team in November 2020 according to the methodology reported in EPA 435/1995 reference (EPA Method 21) and UNI EN 1544 standard. By using a certified portable FID/PID analyzer, the monitoring was conducted on four of the five valves, as one valve was not operating at the time.
Sand Consolidation Treatment: Durability in an Alternative Primary Sand Control Method for a Marginal Reservoir
Authors: Kueh Jing Zhi , Tan Kok Liang , Dev Daevin , Thamilarasu Mohana Ramanee , Abd Wahab Syafiqa , Riyanto Latief , Hashim Saharul , Balasandran Anandhadhasan , Kristanto Tutus , Ramirez Cristian , Chen Yee Choy 
Published: February 2022

Abstract
Field A is mature hydrocarbon producing field located in east Malaysia discovered in 1963. With multistacked reservoirs more than 7,000 ft high, the reservoirs are predominantly friable and unconsolidated, requiring sand exclusion from the beginning. Most of the wells were completed using internal gravel pack (IGP) methods in the main reservoir. Being an aging producing field, many of the main reservoirs have been depleted and watered out, making the wells inactive. There are, however, several shallower marginal reservoirs, which have been bypassed and undeveloped, known as behind casing opportunity (BCO) reservoirs. The challenge is accessibility to this sand prone reservoir, which might require substantial workover operations, and thus higher costs. Remedial options with proven screen completion can be costly and economically difficult to justify.
Mid-2020 marks seven and a half years since the application of a single treatment of epoxy resin in an idle well located in Field A as a remedial approach for BCO. The treatment, proven economically attractive by yielding cost savings of USD 5 million compared to the workover option, further supported by rigorous production monitoring, is unequivocally valuable based on the duration of sustained sand-free production, once again providing reassurance in making this solution a reliable sand-control remedial method for marginal reservoirs.
It is important to note that the solution considered a range of laboratory data associated with the chemicals that effectively addressed the requirement based on the characteristics typical of this formation. Well test data from 2013 to 2019 supported sand-free production. Despite experiencing an increment of water cut percentages up to 93.29%, the well is still performing at acceptable production rates.
The groundwork processes of candidate identification to the execution of converting the well are described, emphasizing technology comparisons applied in terms of resin fluid system type, execution plan, lessons learned, and best practices developed for maximizing the life of a sand-free producer well.
A Physical Solvent Approach to Blue Hydrogen
Authors: Gilmartin Mike , Graham Curt , Aljazzar Ghaith 
Published: February 2022

Abstract
This paper describes the use of a physical solvent, propylene carbonate, to remove CO2 from existing or new build-Hydrogen Plants (SMR, ATR, or POX) and recovery of that CO2 for carbon sequestration or EOR to produce Blue Hydrogen. The treatment unit is located downstream of the shift reactors and upstream of a conventional PSA. The captured CO2 stream will have sufficient CO2 purity for sequestion or other industrial uses. This paper presents CO2 removal levels, captured CO2 purity, total utilities consumption and other benefits of the process. The results will be compared to a conventional amine-based CO2 removal system.
Fully Coupled 3D Geomechanical and Natural Fracture Modeling for Fracture Propagation Simulation in Unconventional Resources
Authors: Wang Rujun , Zhou Wei , Cui Shiti , Wu Yiming , Xu Hanbing , Ma Hui , Lian Liming , Zhang Jian , Huang Lamei , Tong Kejia , Liu Yu , Yang Lu , Bian Wanjiang 
Published: February 2022

Abstract
Hydraulic fracturing is one of the major production enhancement measures for low permeability fractured reservoirs, where a large amount of oil and gas is stored worldwide. In recent years, during the development and research of these reservoirs, it has been found that the hydraulic fractures formed are no longer the single planar fractures produced by fracturing in homogeneous reservoirs, but complex, non-planar, multiple hydraulic fractures are formed, and the post-fracturing production often shows a positive correlation with the fracture complexity. A large amount of hydraulic fracturing diagnostic data indicates that the interaction between pre-existing natural fractures and induced hydraulic fractures is the key condition leading to the formation of complex hydraulic fractures. Simulation of hydraulic fracture extension in fractured reservoirs requires simulation of fluid pressure changes after the intersection of hydraulic fractures and natural fractures, as well as hydraulic fracture steering and other complex conditions. The traditional hydraulic fracture extension simulation models and theories are no longer suitable for such inhomogeneous reservoir conditions, but the relevant theoretical research is still immature and the interaction between hydraulic fractures and natural fractures during hydraulic fracture extension in fractured reservoirs is still not well understood. It is necessary to further develop theoretical research on hydraulic fracture expansion in fractured reservoirs to understand the mechanism and influencing factors of complex fracture formation, in order to promote the development of field development and theoretical research system of similar reservoirs. In this paper, we simulate and analyze the factors influencing hydraulic fracture expansion in fractured reservoirs. Through a series of numerical simulations, we found that horizontal bedding may open up during hydraulic fracturing to form horizontal fractures, and horizontal and vertical fractures intersect each other to form a complex volumetric fracture network; The distribution length of volumetric fractures increases and the distribution width decreases when the horizontal principal stress difference increases, and the aspect ratio of volumetric fractures increases; the distribution length of volumetric fractures decreases and the width increases when the fracturing construction displacement increases, and the aspect ratio of fractures increases. The residual tensile strength of natural fractures increases, the distribution width of volumetric fractures decreases, the distribution length increases, and the aspect ratio of volumetric fractures increases. The research results can provide some reference and reference for the fracture design and construction of fractured reservoirs.
Scrutinizing Wells Integrity for Determining Long-Term Fate of a CO2 Sequestration Project: An Improved and Rigorous Risk Assessment Strategy
Authors: Patil Parimal Arjun , Hamimi Asyraf M , Abu Bakar M Azuan B , Das Debasis Priyadarshan , Tiwari Pankaj Kumar , Chidambaram Prasanna , B. A. Jalil M Azran 
Published: February 2022

Abstract
Depleted hydrocarbon reservoirs are considered inherently safe for carbon sequestration, but high well density penetrating the CO2 storage reservoir could compromise the containment performance in a carbon, capture & sequestration (CCS) project. Based on the available well data, it is crucial to understand the age of the well, materials used for wellbore construction, cement quality, barriers performance, and well integrity. A risk management methodology can be incorporated to evaluate primary and secondary barriers in existing plugged and abandoned (P&A) and development wells to ensure long-term fate of CO2 sequestration project.
Existing P&A wells and development wells in a depleted field were drilled 3–5 decades ago. The wellbore construction utilized non-corrosive resistant materials. Health of all wells that ever penetrated the CO2 storage reservoir need to be analyzed from long term perspective of storing CO2. Throughout the lifespan of wells, subsurface barriers should maintain hydraulic isolation to prevent leakage happening from subsurface to environment of reservoir fluids and injected CO2. Deterioration of strength of wellbore construction material due to corrosion, induced by downhole pressure and temperature conditions, should be considered. This study investigated 3 exploration and 21 development wells. Risk register was developed for each well describing causes and CO2 leakage risks, impacts and consequences. Metrics were defined for parameters such as well age, well head materials, wellhead functional test and leak test, sustained casing pressures for risk determination. Wells were risk rated individually based on the assessment. Wells with low risk can be utilized for well conversion. While for high-risk wells, an opportunity risk matrix was developed to mitigate risks in all the wells.
This study evaluates the well integrity and CO2 leakage risk along the wells that penetrated the CO2 storage reservoir. The improved rigorous risk assessment exercise evaluates well barrier failure causes and impacts along with estimating the risk number per well. The well risk assessment score calculated was between 9.24 and 13.35 for 21 development wells. Out of these 21 wells, 4 wells with risk score &lt;10 can be utilized for wells conversion. Specific barrier restoration process by additional scope of work such as lower completion removal including packer milling, intermediate casing removal, or installation of downhole permanent barriers with remedial cement is discussed for designing the well abandonment process to minimize leak potential of high-risk wells for ensuring long-term containment security. Improved rigorous well integrity risk assessment for CO2 storage field is decisive for any CCS project economics that utilizes barrier identification process and remedial actions.
Innovative Technical Strategies in Natural Fracture Characterization for Well Placement: Case Study from Darajat Field, Indonesia
Authors: Joonnekindt Jean Pierre , Diaz Francisco , Davies Russell , Hultzsch Paul , Mulyani Sri , Intani Rindu , Putra Fanji , Meiyanto Meiyanto , Nordquist Gregg , Golla Glenn , Gunderson Rich 
Published: February 2022

Abstract
The Darajat geothermal field, located in West Java, Indonesia and operated by Star Energy Geothermal, has a long history of production with about 30 wells in which image log data are available. The subsurface geometry of the field was characterized initially from remote sensing methods and surface geology to locate the intrusions, faults and rock units comprising the reservoir, and later validated by well data. Reducing the uncertainty in future well locations depends on models of natural fractures applied and used successfully in oil and gas reservoirs, and associated permeability sweet spot maps. The modeling of natural fractures is determined by results from "drivers" calibrated to fractures interpreted in borehole image logs. These drivers most typically include distance-to-fault as in a damage zone, but also geomechanical methods that model fractures in the perturbed stress field around mapped faults. We modified the drivers to include the effects of the pressurized volcanic intrusions and their cooling for this geothermal field. These drivers were applied in sequential steps and fractures generated from the driver-specific constraints were compared against those observed in the well log images to define an intensity. In this paper we describe novel methods to characterize fractures to generate sweet spot maps for drilling locations in the Darajat geothermal field.
A Novel Portland Cement for CO2 Sequestration by Nanoparticles
Authors: Tiong Michelle , Gholami Raoof , Li Yisong 
Published: February 2022

Abstract
Global warming is a critical issue that has garnered significant attention during the last few decades. This temperature increase results from the emission of greenhouse gases into the atmosphere, most notably CO2. Carbon Capture and Storage (CCS) technology has been established as one of the most successful ways to store CO2 in underground layers and prevent it from being released into the atmosphere. However, CO2 is difficult to contain in subterranean layers subjected to high-pressure, high temperature (HPHT) conditions due to the degradation of Portland cement caused by chemical interaction with wet/dry CO2. Numerous studies have been conducted to increase the cement's resistance to CO2 attack, but limited effectiveness has been found when these methods have been evaluated under various settings. Given the distinctive properties of nanomaterials, such as high surface areas, quick contact, and resilience to heat, Nano Glass Flake (NGF) and Multiwall Carbon Nano Tube (MWCNT) were deemed to be suitable additional materials for increasing cement efficiency.
On cement samples treated with NGFs and MWCNTs, a number of pre-carbonation and post-carbonation tests were performed. The pre-carbonation tests revealed that the density of NGFs-based cement remained constant with that of neat cement while the plastic viscosity increased. Additionally, it was recommended not to add more than 1wt% NGFs to the cement, as this would result in a high viscosity paste, which would negatively affect the pumping operation. On the other hand, this threshold for the viscosity of MWCNTs was roughly 0.25wt%. It was found that by using nanoparticles and employing a proper dispersion process, the cement's overall physical performance can be improved, and a lower amount of Portlandite is formed, which is critical for increased resistance to CO2 attack.
In a static reactor, samples with the best pre-carbonation performance were subjected to water saturated supercritical CO2 for 56 days. It was then discovered that CO2 diffuses into cement and increases cement decomposition in the post-carbonation stage of the experiment. Samples weighing more than 0.5wt %. NGFs and 0.05 wt% MWCNTs had the smallest carbonated regions, indicating carbonated cement. However, the number of nanoparticles added to each sample resulted in a variable level of carbonation. Cement made using MWCNTs has a higher compressive strength due to its ability to manipulate CaCO3 crystal shape. NGFs-based cement, on the other hand, could be a better solution in terms of CO2 resistance. Due to their substantially lower cost than MWCNTs, it is possible to increase cement performance in CCS operations without imposing a high cost on projects.
Optimizing Hydrogen Kinetics for Zero-Carbon Emission Transport Technologies
Authors: Park Ji-Woong , Pei Yuanjiang , Zhang Yu , Zhang Anqi , Som Sibendu 
Published: February 2022

Abstract
To achieve carbon neutral ambition, hydrogen (H2) has recently received significant attention as a zerocarbon fuel for internal combustion engines (ICEs) across transportation sectors. As a critical element in the analysis-led design process, a hydrogen kinetic mechanism needs to be thoroughly evaluated to support the development of high-efficiency H2-ICE combustion system concepts. In this study, recently published H2 kinetic mechanisms were reviewed and down-selected for evaluations against available laboratory data in ignition delay time (IDT) and laminar flame speed (LFS) measurements. The examination was subsequently extended to high-fidelity three-dimensional (3-D) computational fluid dynamics (CFD), spark-ignited, H2 engine simulations. Discrepancies identified at engine-relevant conditions led to a kinetics tailoring campaign based on the H2 mechanism developed by Burke et al. (2012). Selected reactions identified via global sensitivity analysis were optimized under the engine-relevant pressure-temperature conditions. The reaction rate coefficients were adjusted within the experimental and theoretical uncertainty limits by adopting a Monte-Carlo sampling approach as a searching algorithm to generate candidate mechanisms. Finally, the optimized mechanism was validated sequentially from low-dimensional (0-D and 1-D) to high-fidelity 3D CFD engine simulations. Overall, the optimized H2 kinetic model led to significantly improved predictions on capturing engine in-cylinder pressure trace and heat release rate.