bluuebunny/crossref_metadata_2025 huggingface dataset:
Estimation of the Static Young's Modulus for Sandstone Reservoirs Using Support Vector Regression
Authors: Mahmoud Ahmed Abdulhamid , Elkatatny Salaheldin , Al Shehri Dhafer
Published: February 2022

The static Young's Modulus (Estatic) is an important parameter affecting the design of different aspects related to oil and gas producing wells. It is significantly changing based on the type of the formation, and hence, an accurate method of identifying Estatic is required. This study evaluates the performance of support vector regression (SVR) for prediction of the Estatic. The SVR model was learned to evaluate the Estatic from the well logs of the bulk formation density in addition to compressional and shear transit time. It was learned and tested on 592 training datasets of the inputs and their corresponding Estatic, these datasets were obtained from a sandstone formation in Well-A. The learned SVR model was then validated on 38 data points from Well-B, the performance of the optimized SVR on predicting the Estatic for the validation data was also compared with these of the early optimized artificial neural networks (ANN) and functional neural networks (FNN). As a result, all machine learning models showed high precision in predicting the Estatic for the validation data where Estatic was estimated with average absolute percentage errors of 3.80%, 2.54, and 2.03% and correlation coefficients of 0.991, 0.997, and 0.999 using the optimized ANN, FNN, and SVR models, respectively. This result shows the high accuracy of the SVR on predicting the Estatic.
COVID-19! Business as Usual in the Rigless Operations: A Case Study from Saudi Arabia
Authors: BinZiad Abdullah , Al-Subaii Abdullah , Alharthi Saleh , Alotaibi Abdulmajeed
Published: February 2022

Last year, the oil and gas industry was hit with one of the biggest challenges in the history of the industry — COVID-19. This has been a pandemic no one imagined would cripple the whole world and threaten our very existence. It caused an imbalance to the oil supply and demand where the global oil market had more than it could use or store, which drove oil prices to a record low. Despite this, projects in development have to be completed to accommodate the future rise in demand that is expected to occur after the pandemic. This paper will showcase how the rigless operations in Saudi Arabia in the oil and gas fields managed to continue with their activities toward tackling this challenge by capitalizing on two main principles. The first principle was business continuity management; preparing a strategic and operational framework to actively increase resilience to prevent suspension of the rigless operations or services, and thereby fulfilling the industry demand and preventing a cash flow interruption to the stakeholders. The second principle was the risk management process (RMP); identifying, monitoring, and managing all risks related to COVID-19, which minimized, and in some cases eliminated, its impact on the rigless operations.

Both principles were the main pillars to first preserve lives and second to assure business continuity, which resulted in the continuation of the rigless operation and the profitability under the COVID-19 challenge for the company. COVID-19 was a risk no one accounted for. It was a true test to business continuity management and the risk management process. The integration of both processes in the oil industry, and specifically in rigless operations for the first time due to this pandemic, was essential to overcome the COVID-19 crises in addition to tailoring specific steps to address this challenge. Therefore, the rigless operations continued with planned activities while preserving people's lives.
Risk Assessments to Improve Workplace Compliance and Safety
Authors: Boyd Leah , Mills Laura , Jacintho Andrea , Martinez Gus
Published: February 2022

Extended Abstract

For companies with work sites around the globe, assessing risks is challenging—particularly since many sites in different countries must adhere to different rules and regulations. This paper reviews a novel template developed by Siemens Energy to assess risks on a "level playing field" for each of its manufacturing centers, offices, and in-field work locations. The risk assessment template allows facilities to be ranked based upon their environmental, health, and safety (EHS) risks as well as ISO requirements incorporating quality and EHS standards.
The Use of Health Management Programs for the Contractors Workforce
Authors: Alzain Hassan , Abu Qurain Ali , Al-Jaafari Abdulrahman , Hall Jason
Published: February 2022

This paper aims to detail key success factors in understanding the effective principles of managing the health and well-being of the contractor workforce during and post pandemics, specifically for organizations in the oil, gas and energy industry. Furthermore, it shall provide insights and guidance on how to maintain and enhance contractor workforce experience, particularly during and post the COVID-19 pandemic; detailing the benefits of having well-established health management programs designed specifically for the contractor workforce.

The social determinants of health (SDH) can be defined as the social and economic conditions in which people are born, grow, live, learn, work and age. They are nonmedical factors that influence a vast range of health conditions; affecting individuals' overall quality-of-life. Economic policies, social norms and political systems are all examples of forces and factors that shape daily life conditions and affect human health (ODPHP, n.d.; WHO, n.d.a). SDH also encompasses education, employment, socioeconomic status, access to health care, social support as well as neighborhood and physical environment (Artiga and Hinton, 2018). SDH have a crucial influence on health disparities and inequities – "the unfair and avoidable differences in health status seen within and between countries" (CDC, 2020).

A well-known key factor in the emergence and perpetuation of health disparities is housing. Several researchers from a diverse array of disciplines explored the various aspects of the association between housing, health and well-being. They endeavored to comprehensively elucidate the major pathways through which housing conditions can negatively impact health equity, with a focus on the broad spectrum of hazardous exposures, their accumulated impact and their historical production. As reported by Rolfe et al. (2020), there is compelling evidence of poor physical health consequences of toxins within homes, damp and mold, cold indoor temperatures, overcrowding, and safety factors. Beyond the aforementioned impacts of physical aspects of housing on physical health, poor housing conditions have also been linked with high risks of poor mental health and well-being (Pevalin et al., 2017).
Implementation of Selective Laser Melting Technology in Development of Rotary Percussion Drilling Tool
Authors: Li Bodong , Zhan Guodong David , Xu Jianhui , Tu Yulin , Suo Zhongwei
Published: February 2022

Metal additive manufacturing, also known as metal 3D printing, offers alternative ways to produce complex components without design constraints compared with traditional subtractive manufacturing methods. As a sub-category of metal additive manufacturing, selective laser melting (SLM) provides many advantages including high as-printed material density, good mechanical properties, and short production cycle, etc. This paper discusses the technical insights on implementation of SLM technology in development of a rotary percussion drilling tool – hydro-efflux hammer. The objective is to improve the quality and reliability of core components of the hydro-efflux hammer through optimized manufacturing workflow with SLM, for enhanced tool performance and extended tool life.
Safest Available Technology to Reduce the Blowout Probability in High-H2S and High-Pressure Drilling and Completions Applications While Using a Surface BOP
Authors: Kabdolov Altynbek , Feltracco Davide , Dupal Ken , Jones Reese , Zausa Fabrizio , Gandini Gabriele , Caia Alessandro
Published: February 2022

With the goal to exhibit leadership in industry process safety, North Caspian Operating Company (NCOC), Eni, and Kinetic Pressure Control have collaborated to evaluate the feasibility and potential process safety benefits from use of the Kinetic Blowout Stopper (K-BOS®) technology in High-H2S and high-pressure drilling and completions and intervention applications from artificial islands in Kashagan field. The study focused on efforts to detect any showstoppers for the application of K-BOS, quantify the reduction in the blowout probability due to its application, and summarize the information currently available about the technology.

Using the Eni proprietary e-wise™ fault tree analysis approach, a quantitative risk assessment was performed to compare the probability of a blowout in Kashagan field using conventional BOP systems to the probability of a blowout with the K-BOS added to the stack. The study also reviewed OEM provided operating procedures, a risk assessment for running the equipment, as well as a feasibility study regarding any height restrictions in the BOP stack and the position of the K-BOS in the stack. The impact of alternative equipment for risk reduction such as additional redundancy was also assessed.

The application of the 13 5/8" 10M K-BOS system during reservoir drilling, completion and intervention operations significantly reduces the probability of a blowout by at least an order of magnitude. For drilling operations in the most challenging Rim portion of the reservoir, the blowout probability decreases by more than 90% and the residual value is below the blowout frequency for Producing Wells.

The improved shearing/sealing capacity and reduced closure time provided by the K-BOS enable a reduced likelihood of a blowout and enhance the risk profile for the oil and gas industry.
Big Data Integration Framework for Processing Petrophysical Data
Authors: Alblushi Maryam , Nasser Khalid , Readean Mohammad , Ghamdi Ahmed
Published: February 2022

Background

Since the introduction of the first electrical resistivity well log by Marcel and Conrad Schlumberger in 1927, the field of petrophysical well logging experienced significant technological advancements [3]. One of the new technologies was Logging While Drilling (LWD), which allows for real time data streaming and acquisition from the initial drilling depth to the target depth. The target depth sometimes reaches more than 25,000 feet, resulting in wealth of captured data [7]. As special logging probes scan given subsurface intervals, a long list of diverse readings is collected as functions of either depth or time [4]. Unfortunately, most of the obtained data cannot be used as is; several processing, calibration and interpretation activities must be performed on the stored raw data to extract useful insights about the penetrated formations [5].

While these data processing activities are plausible for one particular hydrocarbon reservoir using conventional processing techniques, performing field-wide petrophysical studies can be a real challenge. However, big data technologies can be seen as a potential solution as petrophysical data satisfies the main characteristics of big data. Such characteristics include the high volume, velocity, extreme variety of measurement types and formats, and the uncertain veracity of data attained from several vendors and sensors.

In this paper, we first review the major challenges limiting geoscientists, geophysicists and petroleum engineers from fully exploiting petrophysical data. Then, we propose a big data-based framework which can help overcome some of these challenges by capitalizing on advanced processing techniques. Finally, we discuss the results of applying the framework on a defined business case.
Petrophysical Characterization of the Qusaiba Formation, Tabuk Basin, North West Saudi Arabia: Implications for Reservoir Dynamics in a Shale Play
Authors: Amao Abiodun Matthew , Alquraishi Abdulrahman , Alghamdi Faisal , Aref Lashin , Elshreef Khaled , Laboun Abdulaziz
Published: February 2022

The Qusaiba formation is an emerging unconventional play in Saudi Arabia. A detailed study was conducted on acquired representative samples which covered all the units of the Qusaiba formation from three locations in North Western Saudi Arabia. This study was conducted to fully characterized the formation to understand the governing petrophysical factors, their variability in the basin and implications for reservoir fluid dynamics in this unconventional reservoir.

This is a field to laboratory study. A field trip was conducted to the location to collect representative samples at three locations in the Tabuk basin. The formation outcrops were sampled at intervals of about one meter, to ensure a detailed coverage of the sampled Qusaiba formation. The samples were then subjected to detailed mineralogical analysis comprising of XRD, SEM and petrophysical characterization to determine the porosity, permeability, pore size distribution and capillary pressure profile of the sampled formation. Detailed elemental and mineralogical analysis was necessary to understand paleo-depositional environments and infer any diagenesis in the samples.

Results show that the Qusaiba formation is divided into five main units. The basal Unit 1 overlies the Sarah sandstone, it is mainly thinly laminated dark grey shales, with some dark brown, grading into clayey siltstone at the top. Unit 2 is a mix of shales, siltstone and sandstone, Unit 3 is composed of thinly laminated dark-gray black shales, Unit 4 is composed of thinly laminated gray-green shales, with some mixture of siltstone. Unit 5 is a mixture of thinly laminated gray-green shale in the lower parts, thinly laminated gray-beige silty claystone and laminated beige-brown siltstone at the topmost part. Four lithofacies were identified, these are shale, claystone, siltstone and sandstones. The average porosity, permeability and pore radii in the sandstone facies was 14.13%, 8.3 md and 0.1323 microns respectively; in the siltstone it was 14.85%, 7.12 md and 0.1047 microns, in the claystone, it was 9.8%, 11.40 md and 0.029 micros, while in the shale facies it was 18.31%, 8.21 md and 0.0167 microns. It was observed from the pore size distribution plot that the shale samples exhibit fractures sized pore radii in the macro-pore range. These data demonstrate the high heterogeneities present within the Qusaiba formation, especially in the interbedded layers.

The results from this study provide an understanding of the pore structures in the Qusaiba formation and the main lithostratigraphic facies governing reservoir fluid flow. The pore structures of the main Qusaiba lithofacies were characterized extensively, this would enhance the understanding of how to unlock the potentials of this unconventional reservoir. It shows that fractures in the fractured shale units could have high impact on fluid flow.
Collaborative Web Based Platform for 3D Reservoir Characterization and Geosteering Planning on the Cloud
Authors: Santoso Gagok-Imam , Denichou Jean-Michel , Al-Alqum Wael , Zeidan Motaz , Satti Mohammed
Published: February 2022

New developments in Machine Learning and Artificial Intelligence-based interpretations are bringing a step change in the integration of multi-physic evaluations and management of reservoirs in real time. But it also requires game-changing digital developments to deliver the larger computing power required and to facilitate their access to multi-disciplinary (and sometime not co-located) team of experts and decision makers. This communication is sharing our experience of a web-based collaborative platform integrating operator's application used to produce realistic geological models and a service company's advance multi-dimension modeling and inversion supporting latest Logging While Drilling formation evaluation workflows. The system is now routinely used in case studies, allowing users to perform pre-job well placement feasibility analysis and post-job model refinement.

The technology behind is a modular Web platform that hides all the complexity of the modeling and inversions algorithms. Users can;

Upload their data to the application's virtual file system. Visualize 2D and 3D models, Launch modeling jobs for Ultra-Deep Azimuthal Resistivity (UDAR) and conventional formation evaluation measurements and finally monitor the inverted images unfold as the job progresses, all in the web browser.

The system enables multiple users to view and edit the shared models and observe and control the same job in a collaborative way. The simulation codes are run on the remote clusters or on the cloud. We will present the application of platform and models for 3D characterization in Norwegian continental shelf wells. The examples illustrate mapping of 2D and 3D structural complexity and how the system is used to update reservoir geomodels.

The platform is also used to identify optimal well position; define geosteering strategies in the pre-job planning phase, as well as to evaluate sensitivities, depth of investigation in specific scenarios and to analyze how the structural model uncertainties may be affecting the interpretation. Modeling and inversion are used to assess how structural complexities, lithological changes, oil-water contacts and saturation could be encounter in simulating future production. It is a key for quantitative robust interpretation and geomodels update. The platform allows fast deployment of latest research modeling and inversion prototypes. We finally present the latest results of full 3D modeling and various flavors of 2D imaging inversion results from multiple wells, visualized in the browser using a 3D viewer. The new digital solution improves understanding of 3D reservoir structure and fluid distribution around the wellbore.
Can We Predict Primary Creep and Least Principal Stress Shmin at Depth Either from Specific Surface Area or Weak Phase of Gas Shales?
Authors: Mandal Partha Pratim , Sarout Joel , Rezaee Reza , Hossain Mofazzal
Published: February 2022

Recently short-term laboratory primary creep i.e., time-dependent deformation under triaxial in situ stress condition of ultra-low permeable gas shales have been utilized to work out geomechanical impacts of field development cycle such as modification of in situ stress state, prediction of production induced deformation, and understanding of fracture closure mechanism. However, obtaining creep data from the laboratory method is tedious, time-consuming, and costly. A simple power law model as a function of time involving instantaneous elastic compliance of the studied material B, and time dependent component n is used to describe creep and stress relaxation owing to the superposition principle of linear viscoelastic materials. Gas shales usually have a large specific surface area (SSA) because of the dominance of clay minerals (Illite, Smectite, Kaolinite, and Chlorite) and/or total organic carbon (TOC). Low-pressure nitrogen gas adsorption is a quick and cost-effective method to derive specific surface area value SN2 on powdered gas shale samples. From the observed strong empirical correlation between creep parameters and SN2value as well as with weak phase fraction ClayTocPHI (combination of clay, porosity, and TOC), a novel indirect approach is proposed to predict primary creep constitutive parameters either from the specific surface area (SSA) value SN2 or weak phase fraction ClayTocPHI of multiple gas shales at deeper subsurface formations (Figure 1). These gas shales cover a broad range of mineralogy, maturity, porosity, and depositional history. Through a case study, empirically derived creep parameters from SN2 are utilized to predict the least principal stress Shmin magnitude at depth of a six lithological layered gas shale formation with a viscoelastic stress relaxation approach. Direct field measurement validated the layered variation of the predicted Shmin magnitude.
The Potential for Underground CO2 Disposal Near Riyadh
Authors: Corrales Miguel , Mantilla Salas Sofia , Tasianas Alexandros , Hoteit Hussein , Afifi Abdulkader
Published: February 2022

Carbon Capture Storage (CCS) and Carbon Capture Utilization and Storage (CCUS) have recently gained global attention as promising techniques to mitigate net CO2 emissions. Within this framework, the Saudi Arabian 2030 vision targets the large-scale deployment of CCS and CCUS projects to promote its circular carbon economy. This study evaluates the potential for underground sequestration of CO2 emitted from industrial sources near Riyadh, Saudi Arabia, which emit 46 Mton/year.

A deterministic geologic model corresponding to the Unayzah Formation was constructed using published data incorporating sedimentary facies distribution, porosity, permeability, and connectivity. Compositional simulations were performed to assess the CO2 plume flow in the presence of conduits, barriers, and baffles. Similarly, injectivity and injection rate effects on solubility and residual trapping were evaluated. A sensitivity analysis and an uncertainty quantification study were carried out to obtain a probabilistic assessment of the total storage capacity and trapping contributions.

The geological evaluation indicates that the area under Riyadh is unsuitable because the Triassic sandstones are too shallow, and the Paleozoic section was entirely removed by erosion during the Carboniferous. Alternatively, the Hawtah area, at 150 km south of Riyadh, is deemed suitable for CO2 sequestration. These sandstones are porous, permeable, tightly sealed, and correspond to hydrocarbon reservoirs in anticlinal structures along the Hawtah, Nuayyim, and Dilam trends. They are favorable for CO2 disposal outside oil and gas fields due to lateral and vertical permeability barriers and up-dip pinch-out against the Batin arch. Simulation results, fifty years after CO2 injection and two hundred fifty years of monitoring, show that the Unayzah Formation satisfies the conditions of capacity, injectivity, and seal efficiency required for technical feasibility.

Furthermore, lower injection rates promote higher solubility and residual trapping due to gravity-controlled flow exceeding viscous and capillary forces. Residual trapping contributes ~ 50% to the storage, while solubility adds 10%. The variables that have a higher impact on secure trapping are residual gas saturation, water salinity, and permeability. The current CO2 storage capacity in the area evaluated exceeds 300 Megatons (Mt), and the assessment is still ongoing, with no vertical leakage through the caprocks of the Khuff and Sudair Formations.

Overall, the novelty in this research focuses on the unprecedented use of public domain data to construct a detailed geological model of the Unayzah Formation in the Hawtah and Nuayyim area that allowed a better understanding of CO2 flow mechanisms in the reservoir and its capacity to store CO2. This study concludes that the Unayzah reservoir in the Kharj-Hawtah area is a viable candidate for secure CO2 disposal from industrial sources in Riyadh.
An Organic Gel System for Water Production Issues Post Hydraulic Fracturing
Authors: Abdelwahab Omar , Almubarak Tariq , Schechter David , Bhatia Mukul
Published: February 2022

Water production post hydraulic fracturing is an issue that has been facing E&P operators worldwide for a long time. The water quantities produced can be significant with great amount of impurities. This not only reduces the oil production in those wells, but can also cause problems such as sand production, scale, corrosion and erosion. Moreover, it costs the E&P operators a lot of money every year to treat and dispose these produced waters. Crosslinked gels have been used successfully in the oil and gas industry to shut-off water producing zones. This study presents an experimental investigation of a polyacrylamide-based polymer and polyethyleneimine (PEI) system for water shut-off treatments.

The polyacrylamide-based polymer has a molecular weight of 40,000 Daltons. PEI crosslinker was obtained in a 50:50 aqueous solution with a molecular weight of 60,000 Daltons. The HP/HT rheometer was used to conduct the viscosity measurements. All experiments were done at a pressure of 400 psi. The shear rate was fixed at 100 s−1 and the temperature was ranged from room temperature to 350℉. The gelation time and the system's viscosity were both studied as a function of polymer concentration and salt concentration in the mixing water. Additionally, the effect of increasing temperature on the gelation time was examined. Moreover, an HP/HT aging cell was used to generate the gel that was used later for compatibility testing with a treated formation water from the Wolfcamp.

Increasing the polymer concentration was found to decrease the gelation time and increase the system's viscosity up to a specific limit. Moreover, we observed an increase in the gelation time as the concentration of NaCl was raised in the mixing water, however the system's viscosity decreased. Also, we noticed a decrease in the gelation time as the temperature increased. Finally, no incompatibility issues were observed between the polyacrylamide-based polymer/PEI system and the treated formation water.

Polymer-crosslinker systems should be stable and highly viscous to ensure an effective water shut-off operation. This work experimentally investigates the performance of a cheap polyacrylamide-based polymer and PEI organic gel system. The paper shows that the tested system is capable of sealing water production zones and can provide a promising alternative to current water shut-off systems used in the field.
The Contribution of Remote Factory Acceptance Test Towards Project's Schedule, Cost & Quality at Hawiyah Unayzah Gas Reservoir Storage
Authors: Al-Saidi Mansour , Al-Fouzan Hamad
Published: February 2022

This paper shares the Project Management Team's experience of conducting a Remote Factory Acceptance Test (Remote-FAT) at the Hawiyah Unayzah Gas Reservoir Storage project instead of the conventional approach of a conventional Factory Acceptance Test (FAT). The paper also highlights the advantages gained from a Remote-FAT, along with the value engineering created. In addition, this paper will present some deficiencies and areas of improvement. This shared experience is from the point of view as a PMT client or customer. At Hawiyah Unayzah Gas Reservoir Storage (HUGRS), the Remote-FAT approach was used with many disciplines, such as mechanical, electrical, pipelines, etc. This paper focuses on the process control system experience only, from 2020 to 2021. Meanwhile the HUGRS project is in progress and is expected to be completed by 2024.

Conducting a FAT is one of the main milestones in projects. The conventional method is usually to have individuals physically visit the manufacturer to check and approve shipping the purchased devices/equipment to the project site. Sometimes this practice "FAT" takes place in the same country where the project is being constructed. But in other cases, the manufacturer is not even on the same continent, requiring travel of hundreds or thousands of kilometers. During COVID-19, there were many active projects that needed to conduct FAT activities, but travel was suddenly restricted. Therefore, the only option was to proceed with Remote-FAT. One of these running projects is HUGRS.

The Remote-FAT is a virtual inspection check conducted by the client and vendor via online video streaming at the manufacturer location. Multiple cameras are used and located in different views to visualize whatever needs to be seen. In some cases, the Remote-FAT can be conducted through sharing a screen only, such as system graphics and logic test. The client and the vendor verify and conduct the test, following the same steps that they would perform in the conventional FAT. This Remote-FAT had already existed for a couple of years, but many project managers considered it as a fancy tool that did not add value. This evaluation was proven wrong by COVID-19. Remote-FAT has become the most convenient approach recently and adopted around the world. For the past two years, the process control systems engineers at HUGRS conducted many Remote-FATs with different vendors for dissimilar systems. The advantages and disadvantages were recorded as lessons learned — part of PMT practice — and will be shared in the next sections of this paper.
Sensor-Ball: Field Deployment of Autonomous and Untethered Surveillance
Authors: Larbi Zeghlache Mohamed , Bukhamseen Ahmed , Muailu Husain , Abdulghani Ahmed
Published: February 2022

With the evolving sensor technologies and advances in integrated solutions, routine surveys and interventions in oil and gas fields are going through a major revamp. The most recent developments in autonomous and untethered devices set a new paradigm shift in such crucial and frequent well operations. In this paper, field implementation and deployment of the novel Sensor-Ball technology is discussed to highlight success, challenges and lessons learned.

Sensor-Ball is a small device, almost a tennis-ball size that enables autonomous and untethered logging of pressure, temperature, and tri-axial magnetic field amplitude. This intelligent device is self-powered using a battery pack with a battery life that suffices logging a dozen wells in a raw including logging time and data transfer time. The internal memory is designed for large and high definition data rates for high resolution and extended recording. Sensor-Ball is encapsulated in a ruggedized housing that can withstand downhole conditions as the device travels on a free-fall down to the programmed depth, as well as while floating back to the surface. This housing is light enough to enable efficient and flawless return of the Sensor-Ball exclusively under bouncy effect once the attached weight is dropped off.

For the deployment of this innovative technology, new procedures and guidelines are developed to ensure successful journey of the Sensor-Ball. Despite the failsafe features, prejob plan, and risk assessment procedures complement this user-friendly technology and make it reliable, efficient, and easy to use.

The results of the field trial of Sensor-Ball in water supply wells revealed a superior data quality of both log-down and log-up. In fact, during the mission time of three hours only, thousands of feet of high-resolution data were collected. This operation would have taken double the time and a much more wellsite footprint, in addition to increased HSE risk, if a standard wireline/slickline unit was mobilized for this routine operation. Sensor-Ball is a reliable and more advanced alternative to traditional well surveillance methods considering the operational efficiency and comparison with benchmark data. In fact, the footprint, cost and time savings are substantial, especially in an offshore environment where barges are mobilized and operations depend on weather conditions.

This technology is a major breakthrough in the surveillance and logging world as it enables a fully autonomous and untethered acquisition of high-resolution data. Sensor-Ball offered more with less and will ultimately replace traditional surveillance and intervention methods.
Supercritical CO2 Recirculation in Reservoirs for Continuous Storage and Production of Renewable Energy
Authors: Aljughaiman Ibraheem
Published: February 2022

Over the past decades, many countries have started to place emphasis towards electricity production from renewable sources, such as solar and wind, to limit the amount of CO2 emissions in the atmosphere and reduce global warming. However, solar and wind energy are exclusively reliant on climate conditions; thus, secure and continuous power supply cannot be guaranteed. Therefore, maintaining reliable and continuous power supply calls for concepts and implementation of energy storage techniques. CO2 subsurface energy storage is one of the most innovative techniques that could be applied to solve drawbacks of traditional storage techniques such as scale limitation in both capacity and time, low efficiencies, environmental concerns, or high costs.

In this paper, we reviewed and assessed the use of CO2 subsurface energy storage systems by looking at the thermodynamic cycles, machinery, and reservoir conditions. Moreover, a comprehensive study on multiphase flow in porous media has been conducted by looking at capillarity, relative permeability, mass balance, heat balance, thermal properties, and phase behavior. Different well configurations have been compared by performing injection and production simulations to conclude that the use of horizontal injection and production wells is preferred over other proposed well configurations for many reasons such as decreasing the amount of initial CO2 needed to develop and operate the reservoir, covering a large area of the reservoir, and increasing the system's capacity and efficiency.

The findings show that CO2 subsurface energy storage system can operate if certain requirements exist: 1) availability of initial CO2 supply, 2) availability of the necessary equipment and solar, or wind, power plants, 3) safety of the targeted location, 4) two deep, clean reservoirs with high porosity and high permeability and 5) presence of a caprock. Ensuring the existence of requirements determined from this study will allow a safe, large (in terms of capacity and time), efficient, and cheap method to store and produce renewable energy continuously.

In the foreseeable future, the world will inevitably depend on electricity production from renewable sources; therefore, more energy storage techniques have to be developed. CO2 subsurface energy storage systems have to be considered as they can contribute to reducing emissions and global warming, ensuring a secure and continuous power supply, and solving the drawbacks of traditional storage techniques. The outcomes of this paper will contribute to the growth and development of CO2 subsurface energy storage systems
Gas Processing Facility Energy Efficiency in Action Success Stories
Authors: AlMethn Abdulrahman , AlFawzan Mohammed
Published: February 2022

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

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

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

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

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

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.