bluuebunny/crossref_metadata_2025_split huggingface dataset:
Reducing Carbon Emissions in Drilling Operations Offshore Abu Dhabi
Authors: Hinden P-M. , Farrouk H. , Innes G. , Crowther L. , Kustanto S. 
Published: October 2023

Abstract
This paper highlights the carbon emissions reduction associated with the thermal processing of drill cuttings. A case study is presented demonstrating how a major operator in the UAE reduced the carbon emissions of its drill cuttings treatment operation by more than 68% across three of the biggest offshore oilfields in Abu Dhabi.
The operator was utilizing a ship to shore method whereby drill cuttings are stored in skips at the wellsite before being transported 131 km by boat and 163 km by truck to a central processing site onshore for treatment. This method involves two days of travel each way, generating 30 tCO2e per trip.
To reduce the carbon emissions of the operation, the operator utilizes a thermal drill cuttings processing unit closer to the wellsite, eliminating 257,300 km of travel. This reduced the carbon footprint of the drilling waste management operation by more than 5,068 tCO2e while improving project drilling efficiency by allowing more sections to be drilled with oil-based mud.
The solution allowed the operator to recover $5,000,000 worth of base oil for reuse in the drilling operation, eliminating the requirement to ship this volume of base oil from the shore to the rig. In addition, the project has seen 80,000 work hours LTI free operations since it began in September 2021.
Potential Risk Evaluation of Biogenic Reservoir Souring for Decision Support of Water Flooding Field Development Plan in a Giant Offshore Oil Field in Abu Dhabi
Authors: Ashikawa Kota , Ikeda Koki , Iino Atsushi , Hiraiwa Takeshi , Makishima Ken , Nomura Yukito , Al Ameri Saeeda Mohamed , Dada Adedayo , Yonebayashi Hideharu 
Published: October 2023

Abstract
Biogenic reservoir souring is characterized by H2S generation by Sulfate Reducing Bacteria (SRB) typically after the initiation of waterflooding. An offshore oil field in UAE has been developed with dump flooding from an aquifer reservoir and peripheral seawater injection. As the future development plan (FDP), pattern seawater injection in the mid dip was selected to improve oil recovery. To assess the robustness of this development plan, the study aims to understand the mechanism of biogenic reservoir souring and predict its future risk.
Firstly, analytical investigation was conducted to assess the present reservoir souring situation. Secondly, the full-field biogenic reservoir souring simulation was performed using SourSimRL (industrial JIP's program) that works as a post-processor of reservoir flow simulators and predicts the microbial generation, scavenging, adsorption and transport processes of H2S. Lastly, sensitivity analyses were carried out to understand the limiting factors of the biogenic reservoir souring and capture the uncertainties in the prediction of the FDP.
The simulation demonstrated that the reservoir cool-down effect by injecting seawater is limited to the vicinity of injectors due to the high reservoir temperature. Thus, dominant pattern of biogenic reservoir souring is expected to be "biofilm" zone where all ingredients for SRB growth need to be supplied with the injected seawater. The sensitivity analysis also confirmed that carbon source and nutrient concentrations in the injected seawater have a larger influence on biogenic H2S generation compared to those in the formation water. The forecast simulation predicted the gradual increasing trend of biogenic H2S concentration in the produced gas at the field level, which is corresponding to the field water cut increase. However, the severity of predicted biogenic reservoir souring impact is still within the facility design limitation. Thus, the FDP is acceptable in terms of biogenic reservoir souring risk because of the robust design basis. Additional souring mitigations such as installation of sulphate removal unit is considered unnecessary. Although the field-level biogenic H2S is moderate, relatively high biogenic H2S concentrations were predicted locally in several wells. It can be managed by well surveillance at the high water cut wells.
The study managed the complicating field development history, consisting of dump flooding from the aquifer reservoir and peripheral seawater injection, and the FDP deploying pattern seawater injection in the mid-dip. Application of the full-field biogenic reservoir souring simulation significantly contributes to decision support of the water flood-basis FDP and better understanding on potential requirement to mitigate the reservoir souring risk.
Innovative Bit Body Design Unveils Manufacturing Novelty, Improves Drilling Performance and Dogleg Assurance in Rotary Steerable Applications
Authors: Gjertsen O. , Santana R. , Craigue L. , James P. , Andreasen G. , Ross J. , Boualleg R. , Tang K. H. , Li D. , Mendoza D. , Gatell J. , Durairajan B. , Mushinski R. , Karuppiah V. 
Published: October 2023

Abstract
The future of oilfield well drilling is incorporating the capabilities of the rotary steerable system (RSS) on a digital platform. For this capability to be successful, the RSS bottomhole assembly (BHA) must be able to drill the entire planned section and deliver an accurate actual vs. plan trajectory. This operation therefore minimizes the time spent drilling each well and subsequently the carbon footprint of that well. The drill bit plays one of the most important functions in this equation. RSS BHA's call for polycrystalline diamond compact PDC drill bits, which minimize the distance from the cutting structure to the deflection pads. By minimizing the makeup length (MUL) of PDC bits makes it possible to achieve more challenging well profiles while alleviating tool damaging shock and vibration.
To minimize the length of the PDC drill bit, innovation drove a one-piece steel body design incorporating all aspects of the application into the design. The cutting structure was designed to optimize MUL, stability, and durability to match the application requirements.  The bit body was analyzed to determine how best to reduce its length to a practical minimum while maintaining manufacturing capability and reliability. Further optimization on the cutting structure through dynamic simulation, improved cutter balancing, and backrake distribution. Removing the traditional two-piece structure and joining weld reduced the MUL by up to 2.5 in. over a baseline minimum.
The reduction in MUL from the one-piece steel body PDC architecture represented a 37% reduction in the drill-bit length. This reduction brings the cutting structure closer to the deflection point of the RSS with two results, namely an increase in build/turn rate by up to 64%, and reduction in lateral and axial shock and vibration on the average with lower peak values. Reducing the BHA and bit vibration and increasing build and turn rates ultimately reduces nonproductive time, increasing the number of sections drilled successfully in one run. Positive directional driller and customer feedback with multiday reduction drilling time has resulted. The largest impact to sustainability is seen in the reduction in RSS tool failures or prolonging time between tool replacement or maintenance.
A comprehensive design approach was undertaken to create a minimized MUL with the target of improving dogleg severity (DLS) capability and stability. The cutting structure and bit body were also designed to optimize MUL, DLS capability, and stability. Design, material analysis, dynamic considerations, and technology integration are the pillars to delivering the described solution.
Improving Injection Efficiency in CCUS Wells: A Comparative Analysis of Different Completion Designs
Authors: Bona Prakasa , Fraser Murray , Clifford Allen 
Published: October 2023

Abstract
Global investment has delivered a steadily increasing investment in carbon capture, utilisation, and storage (CCUS) projects for the past years. Such interest moves the petroleum industry from pioneering projects towards multi- and large-scale projects. Industrial-scale CCUS is necessary to meet the demand of climate change initiatives. Numerous subsurface studies have investigated the potential geology for carbon storage and depleted gas reservoirs are considered as appealing targets for carbon dioxide (CO2) sequestration because of their storage capacity, proven sealing capability, reservoir characterization knowledge, existing infrastructure, and potential for enhanced gas recovery.
While depleted gas reservoirs are attractive targets for CCUS, the CO2 injection process poses several challenges including extreme cooling due to gas depressurization, a potentially unstable flow regime that has consequences for tubing stress analysis, CO2 deliverability, and reservoir management. Careful well design is critical to answering these challenges. Holistic but practical simulation work is key to ensure that the well is properly designed for all types of operations along its injection lifetime.
This paper introduces for the first time, a trifecta of simulation works that links steady-state simulation, transient simulation, and advanced completion stress design. The 1D steady-state and transient analyses would feed into the meshed well-reservoir simulation which enable engineers to investigate the detailed wellbore hydraulics and multiphase flow through advanced completions. These details will be keys as input for analysing the stress and loading simulator. Streamlining these simulations will bridge the communication between the subsurface team and well design team to produce an optimum completion design based on comprehensive analysis. We investigate the behaviour of each of the completion options such as a simple monobore completion, concentric, horizontal wells with inflow control devices and intelligent completion with downhole control valves. The results are then benchmarked to each other with consistency for neutral comparison.
Effective CO2 injection entails finding methods for optimising the fluids along the pipeline and the CO2 voidage once the fluids have entered the reservoir drainage. This paper explains a proposed guideline for effective CO2 injection management. We discuss multiple gains and limitations of each completion which cover hydraulics, thermodynamics analysis, material selection, and tubing stress analysis for different scenarios. This paper also discusses phase instability of CO2 transportation within injection systems which can be avoided by maintaining the proposed guidelines.
A Novel Modeling Enhancement of Emulsion in Condensate with High Aromatic
Authors: Sagar S. F. S. W. , Halim N. H. , Amir M. I. M. , Hendraningrat L. 
Published: October 2023

Abstract
At surface facilities, a gas field with condensate and a severe oil in water/reverse emulsion problem was observed. Due to the emulsify-prone nature of liquid production, this field suffers from Oil in Water content. Current modeling prediction tool cannot be used to predict the severity of the condensate emulsion problem because its application is restricted to black oil. This paper describes enhancements to the modeling of condensate with high aromatic mixtures.
The process flow for testing the enhancements to the modeling is as follows: At first, a large number of laboratory experiments were carried out. These experiments included the measurement and characterization of the mixture's composition, as well as the formation of an emulsion despite variations in the process's parameters, such as shear rate, temperature, pH, and solid content. To develop correlations in order to enhance the applicability of inhouse Emulsion Stability Tool by changing fluid and process parameters in preparation for future emulsion monitoring and the optimization of process facilities at condensate field. The generation of output data of Turbiscan Index (TSI) and Turbidity were accomplished through the development of a multi-equation model of data sets. The following parameters have been agreed upon and will serve as the Key Performance Indicator (KPI): &gt; 80% of measurements in the laboratory should correspond to the model's predictions, and these predictions should be validated with data from the field.
Through the multi-correlation method, an improved modeling has been developed for condensate emulsion. During the validation process between the measurements taken in the laboratory and the predictions made by the model, the accuracy of the model reached 94% using 396 sets of trained data. During validation with actual field data, it achieved a perfect score of 8 out of 8 trained data points. It concluded that KPI has been achieved based on those parameters.
This modeling enhancement is a novel tool that can predict emulsion in condensate with a high aromatic composition to an exceptionally high degree of accuracy. It can provide early detection of emulsion issues for corrective measurement, also known as the optimization of de-oiler dosage. It has the potential to generate added value by lowering the cost of sampling, reducing the number of laboratory tests required for bottle testing, and preventing improper facility design.
A Holistic System Optimization Method to Maximize Energy Savings Within Existing Pump-Systems
Authors: Teesink P. J. , Hurst R. , Bastiaansen T. , Thomas T. , White B. , Carrillo J. Lopez , Butz V. 
Published: October 2023

Abstract
The increasing urgency to act on decarbonization and energy reduction targets has many Oil and Gas operators looking to emerging technologies: Green Hydrogen, Electrification of combustion processes and Carbon Capture and Storage (CCS). The timeline to effectively implement these technologies and the required infrastructure is significant. Starting from licensing, engineering, and procurement to commissioning their impact on carbon and energy can be considered part of a long-term strategy. To meet short term objectives, these initiatives need to be combined with improving the energy efficiency and associated reduction of scope 2 emissions of existing assets. This pursuit is competing for resource and capital priority with the range of asks an operational process plant pose: reliability programs, de-bottlenecking, and margin improvement projects. In a refinery, 50-60% of all electricity is consumed by pumping systems [1] with significant opportunities to improve [2]. Because of the scattered nature of this energy consumption (an average sized refinery process requires over 1000 centrifugal pumps), the key to unlocking this potential is a programmatic, data-driven approach that covers all aspects of energy efficiency: process needs, conversions and control. This paper presents a novel approach to that query.
Personal Protective Equipment Detection Using Computer Vision Techniques
Authors: Aldossary R. S. , Almutairi M. N. , Alotaibi N. M. , Serkan D. 
Published: October 2023

Abstract
The intensive use of chemicals, machines and electrical assets introduced unsafe conditions to the workplace. An unsafe condition is a physical condition that can cause an incident, such as operating without training, defective supplies and poor housekeeping. Such conditions might cause serious injury or even death. As well as the human impact, unsafe conditions have a significant impact on operational excellence and the financial state of a company. Companies are committed to ensure a safe environment by setting safety polices, conducting safety training, fire prevention systems, safety manuals and signboards and providing safety gears. Personal protective equipment (PPE) is safety equipment that can maintain the safety of employees in hazardous conditions, such as hot surfaces and toxic chemicals that can cause serious injuries and illness. PPE is sometimes referred to as the last line of defense. Some workers might not comply with safety policies or refuse to wear the PPE. To overcome the manual safety checks and compliance of employees, in this paper we propose an AI-powered computer vision automation solution leveraging the state of the object detection model. Computer vision is the field that mimics human vision to extract purposeful information from videos and images. Computer vision brings about various functionalities to perform tasks such as object detection, object classification, object identification and object verification. The proposed solution is developed by using a computer vision technique that detects various types of PPEs in real time. The main purpose of this project is to detect a presence of eight classes (person, helmet color: Red, Yellow, Blue and White, head, vest, glasses). The best results were achieved by applying the tunned YOLOv5 on a set of construction site images with corresponding annotations in YOLO format. The proposed solution automates the process of detection and monitoring PPE and employee behavior in operation fields in real-time. Automating the detection can reflect the business value by reducing the timeframe for tracking, creating a safe environment that in turn can increase the productivity and safety of the workers and reduce the costs of operations. The proposed solution includes all the components of data ingestion, data processing, object detection model and deployment on the edge device or server to improve safety.
Cost-Effective Solution for Highly Deviated Wells in Egypt: The Optimal: Artificial Lift System (ALS) Combination Using Continuous Rod with RRP
Authors: Tharwat M. A. , Ariza Gonzalez G. A. , Naguib A. H. , Connally D. R. , Mohammadain A. , Awadallah M. , Farouk E. M. , Halawa I. , Ghareeb M. , Salem A. 
Published: October 2023

Abstract
The oil and gas (O&G) industry has long believed that rod-driven artificial lift systems (ALS) are only suitable for vertical wells. Therefore, Electrical Submersible Pumping (ESP) has been the preferred option for highly deviated wells due to the risks associated with tubing and sucker rod wear. Nonetheless, ESPs are expensive and require high power consumption. When ESP Operational Expenditure (OPEX) becomes too elevated over time, operating the well is no longer economically feasible. This paper proposes an optimal ALS combination for an oil application with challenging wellbore geometry in Egypt, using a cost-effective ALS resulting in lower power consumption and fewer workover intervention expenses to improve lifting costs in highly deviated wells.
The Fadl-3 well is a highly deviated well in Egypt with a dogleg severity (DLS) value of 11.70°/100 ft and 300 pounds-force (lbf) side load. Initially, the well was completed with an ESP as the primary ALS, but over time, the production started declining, and the energy consumption required by the ESP was high, making it unsustainable to operate with this expensive ALS. The operator sought a more cost-effective solution, and in Egypt, rod-driven ALS such as Reciprocating Rod Pumping (RRP) and Progressing Cavity Pumping (PCP) have always been considered too risky for highly deviated wells. However, by combining RRP or PCP with continuous rod, the side load has been decreased to 9 lbf, minimizing the risk of failure due to tubing wear, rod parted, or any other intervention resulting from aggressive wellbore geometry. Continuous rod works with a minimum of two coupling connections, one at each end of the rod string, making it a valuable alternative for deviated or horizontal wells by distributing the contact load throughout the entire rod string length, eliminating high contact load value sections.
This paper demonstrates how the combination of RRP with continuous rods can be an optimum solution to overcome the challenges of using a rod-driven artificial lift in aggressive wellbore geometries. The results of this application in Egypt, where RRP was combined with continuous sucker rod string in a highly deviated well, prove how to make the transition from an expensive ESP technology feasible to a more cost-effective solution to accelerate the return on investment. The ALS solution provided 40% OPEX related to power consumption and 25% cost savings compared to the previous lift systems deployed in this well. The Fadl-3 well has been in operation using RRP and continuous rod since May 2022, producing 100 barrels of fluid per day (BFPD), 38 °API, 50% Water Cut (WC).
Estimating Relative Permeability and Capillary Pressure Functions from Unsteady-state Core Flooding Data Using Dynamic Optimization Techniques
Authors: Kalule Ramanzani , Alfazazi Umar , Ahmed Shehzad , Abderrahmane Hamid Ait , Alameri Waleed , Sassi Mohamed 
Published: October 2023

Abstract
Accurate estimation of the relative permeability and capillary pressure functions is necessary for effectively managing oil and gas reservoirs. Various methods for estimating these properties exist, but mathematical modelling-based strategies have shown promise for accurate estimates. We propose a Pyomo-based mathematical modelling dynamic optimization approach for estimating relative permeability and capillary pressure functions from unsteady-state core flooding experimental data. The approach solves the inverse problem to estimate the unknown function parameters that characterize the evolution of relative permeability in the porous medium and the forward problem to verify the accuracy of the estimated parameters and estimate the capillary pressure function trend. Our results demonstrate the effectiveness of the proposed method in estimating relative permeability and capillary pressure functions from unsteady-state core flooding data and highlight the potential for this approach to enhance reservoir management strategies.
Ground Robotics: A Comprehensive Journey Towards Remote Operations
Authors: Munoz Jean Michel , Bartoli Eric , Collin Gildas , Grenier Philippe 
Published: October 2023

Abstract
Normally Unattended Facilities have a significant cost reduction potential. They represent substantial technical challenges both for their design and for their operability. In our vision, operability is based on a new concept of operations with the presence of resident robots on site. However, this technology is emerging for Oil & Gas applications. This paper presents a methodology applied at TotalEnergies to qualify these solutions and accelerate their deployment on site.
Preparing to deploy a completely new technology in a context of a traditional industry and where all the technological bricks are not yet mature or even not yet well identified is far from obvious. Moreover, waiting for everything to be ready and tested before considering using the technology could take a while and delay the anticipated benefits. In order to be ready to deploy this new operating mode as soon as possible, TotalEnergies has embarked on a progressive qualification program with a succession of on-site pilots of increasing complexity and more and more integrated into the field operations organization.
This progressive approach with the definition of predefined areas of progress has allowed a sequence of successive pilots taking into account, little by little, all the components of the robotic ecosystem that goes well beyond the simple robot. The paper will present through the history of our previous pilots in North Sea, Europe and Middle East, the preparation of our last pilot on an FPSO in Africa with all the technological bricks developed for a complete integration and adoption of this new operating philosophy in our operations in order to ensure scalability to any type of site. Among these bricks, the emphasis will be placed on the field operation operator experience from the definition of missions with the customization of the existing maintenance engineering tools, to the management of a fleet of autonomous robots, the analysis of data and the necessary evolution of the field operations methods.
The paper proposes an evaluation scale to progress in the adoption of an on-site robotic solution and presents the main characteristics and first feedbacks of the latest and most complex robotic pilot of TotalEnergies.