bluuebunny/crossref_metadata_2025_split huggingface dataset:
Onshore Electrified Rig, A Sustainable Strategy
Authors: Dumoulin Mélissa 
Published: October 2023

Abstract
TotalEnergies is a major global energy company with significant operations in oil, gas and renewable energy sources. The company Net Zero 2050 ambition sets a strategy to mitigate its carbon footprint and limit global warming. Reducing the carbon emissions across its value chain is a key aspect of reaching these ambitions. It involves adopting cleaner technologies and thus powering rigs with electricity instead of diesel engines for onshore drilling operations.
TotalEnergies is operating two electrified rigs in Tempa Rossa onshore field in south Italy. During the Gorgoglione-2 (GG-2) drilling project, multiple data have been collected to assess the potential of the rig electrification.
Thus, this paper presents the implementation and the benefits of an electrified drilling rig provided by a gas turbine on the nearby plant. The GG-2 drilling project’s data are used for the following purposes. To highlight the role of the different equipment and their articulation.To acknowledge the fuel gas consumption required to generate electricity and the cost associated.To calculate the GHG net saving and the cost saving applied to Gorgloglione-2 drilling project.To estimate the gain for future projects.
The objective is to give an overview of the rig electrification in this onshore context to provide guidance to other Oil and Gas (O&G) Operating affiliates willing to consider it.
Developing Mature Oil Rim Reservoirs with Large Gas Cap and Weak Aquifer: Key Decisions and Approach, Using A Mature Field in Oman as Case Study
Authors: Kumar G. , Khadhuri S. , Gharbi M. , van Neck H. , Hajri Y. , Yazidi R. 
Published: October 2023

Abstract
This paper describes key decisions and approaches that can be taken to help decision making for late life development of oil rim reservoirs with large gas cap and weak aquifer, with a case study from a mature field in Oman. The integrated approach evaluates different development options for economics, reserves addition and GHG emissions, and recommends the best one as per project value drivers.
Field X has been producing for more than 35 years, first 20 years on primary depletion, followed by produced gas re-injection which is continuing till now. The power and fuel requirements for compressing and re-injecting the gas makes production from this field very GHG intensive. Recently, production from the field has dropped significantly, even though current oil recovery factor is low. The asset team did a full analysis of recovery, GHG and economics to compare various development options, and recommended the optimum development plan based on project value drivers.
Field X currently produces relatively small amount of oil with large amount of associated gas at ~50% water cut and emits large amount of GHGs for a barrel of oil. Water flood development adds incremental oil reserves but requires drilling of additional water injectors and new horizontal producers, which adds to the project capex. Gas blowdown on the other hand erodes oil reserves, but it requires very little additional capital, and reduces lifecycle GHG emissions significantly. Start of gas blowdown timing has interesting impact on the project economics, which gets further complicated by trend of overall gas demand.
Overall, the trade-off exists between incremental oil reserves and NPV on one side and capex and GHG emissions on the other side, for different development options. The best development option in this case was to continue with water flood given promising pilot results. However, the full analysis must be done on case-by-case basis and will depend heavily on oil price and gas demand.
Usually, the development options are evaluated for reserves and economics. In this case study, the analysis was expanded to include lifecycle GHG emissions, while evaluating development options. It was quite a challenging piece of work, further complicated by gas demand forecast and supply forecast from other fields in overall demand supply balance. The analysis can be replicated by other projects, with modifications if required on case-by-case basis.
Increasing Electric Submersible Pumps Run Life: How to Mitigate the Impact of Sensor Data Loss?
Authors: Guillca L. N. , Enriquez L. , Batallas E. , Reyes C. , Tagarot G. , Campana D. , Segovia R. , Andagoya K. , Hidalgo M. , Naranjo R. , Villabos J. 
Published: October 2023

Abstract
Performing a health check on electrical submersible pumps (ESPs) is possible using measurements from the downhole and surface gauges. The downhole data lost significantly reduces the detection of operational issues (i.e., gas lock, recirculation, etc.), and shortens the life expectancy. This analysis summarizes the reasons and impact on the reliability when losing downhole sensor data in a mature field with 230 active ESPs exhibiting 1,580 days of mean time between failure (MTBF).
Seventy-two cases of ESP strings with sensor data loss were analyzed during 6 years of operation using their failure reports, pulling reports, and failure analyses.
Using statistical methods and root-cause analysis tools, the average running time that an ESP survives without sensor data transmission in comparison with the systems with full data transmission was calculated and plotted.
In this paper, we identify the causes of sensor data loss, which are events related to data transmission system (40%), operational conditions (37%), mechanical events (19%), and electrical events (4%).
Innovative Analytical Approach to Eliminate Repetitive Unmanned Offshore Oil Platforms Interruptions
Authors: Ghanem Hashem H , Georgiou Ioannis , Mana Khaled A 
Published: October 2023

Summary
More than 50% of the outages (trips) are attributed to malfunctioning Emergency Shutdown (ESD) systems. Therefore, it is deemed necessary to upgrade these aging and obsolete systems with the latest up to date technology. 39% of the offshore oil platforms outages are attributed to hydraulic system failures. This analytical approach can be applied to any offshore oil field for minimizing the undesirable trips and developing control methodology of the oil field outages. Part of the assessment methodology that needs to be considered is to study the repetitive outages seasons. This is to predict the timeline of the outages and identify the root causes to reach the proper solution. This analytical approach can be applied to any offshore oil field for minimizing the undesirable trips and developing control methodology of the outages.
Achieving Zero Routine Flaring from Block 60 Oil Production Facilities
Authors: Al Siyabi Manal , Al Ajmi Arwa 
Published: October 2023

Abstract
This paper illustrates the study undertaken by OQEP to comply with the goal of Zero Routine Flaring (ZRF) from oil producers by 2030 as mandated by the Ministry of Energy and Minerals (MEM). The ZRF goal is one of the numerous global initiatives toward achieving Net Zero Emissions by 2050 as per the Paris climate agreement. The study conducted by OQ Exploration and Production (OQEP) concept team is applied to flare recovery from Block 60 On-plot oil processing facilities. This article will focus on the methodology used to recommend the most optimal solution to recover an associated gas range of 0.5 MMSCFD to 3 MMSCFD.
The article describes the concept selection process carried out by the concept team at OQEP, to identify both the concept evaluation criteria and a divergent range of possible options to recover and utilize the flare gas. OQEP Opportunity management system policy was followed to conduct this study where the project was taken through an initiation stage to identify the challenge including identification of decisions and evaluation criteria, feasibility assessment where a wide array of options was explored and screened, and a final concept selection stage where the screened options were further optimized for final concept selection. To ensure an optimal concept was selected a wide array of technologies for recovering the associated gas from the existing on-plot facilities including conventional and novel technologies were explored.
The study noted the impact of the quantity of gas recovered on the final economic and environmental performance, in addition, the number of gas source points were also identified as an important decision as the gathering system can impact both the energy efficiency and the life cycle cost of the project. These decisions have been evaluated against the selection criteria and critical success factors.
Successful Implementation of Waterflood in Mature Oil Fields – A Case Study from South Oman
Authors: Borkent E. , Mufarji M. , Morianta M. , Busaidi I. , Mahrouqi I. , Al Badi M. , Ibrahim A. , Harthy M. , Al Kindi S. 
Published: October 2023

Abstract
Field A is one of the largest oil fields in the South of the Sultanate of Oman. The field was discovered in 1975 and has been in production since 1989 under depletion drive utilizing the aquifer support. The main producing reservoirs are part of the Haima Group, which are characterized by good quality and homogeneous sands, but the oil is viscous up to 1300 cP. After over 20 years of production, depletion levels in the field were getting high and a new development strategy was initiated by introducing water injection.
The waterflood development concept chosen for this mature field was injection deep into the aquifer at about 100 meters below the oil-water-contact. 38 vertical water injectors were drilled at regular spacing across the field area. As part of the waterflood development, 6 injector wells were completed just below the oil-water-contact as part of a shallow injection trial. These wells are fitted with fiber optics to allow regular temperature surveys and monitor fracture growth. Surveillance in all injectors is done on a regular basis to ensure conformance and prevent significant upwards fracture growth.
The water injection started in December 2014 and ramped up over the following years to the target level. The pressure response from the injection scheme was initially slower than expected especially in the crestal area of the field. A comprehensive water injection performance analysis was conducted, and several remedial actions were initiated by the team to improve waterflood performance. As water production from the field itself was below the forecasted rate, make up water was brought from nearby fields.
After overcoming the initial challenges, the field is now injecting as per the target rate. And a clear response to the waterflood has been observed through an increase in reservoir pressure. The estimated recoverable volumes increased by about 10%, a very significant addition. The increase in reservoir pressure has also helped to conduct many WRM optimizations like well bean up, artificial lift optimizations and well stimulations. The increase in reservoir pressure has also opened the door to significantly increase field offtake rates through a dedicated conversion campaign by replacing Beam Pumps and Progressive Cavity Pumps by Electric Submersible Pumps. This allowed increased gross offtake and higher net oil production. As a result, Field A achieved record production over 2022, the highest level in 5 years.
Changing the field development of such a mature field has come with numerous challenges, but the success also proves that late field-life waterflood can add significant value. This is replicable to many other oil fields in the South of the Sultanate of Oman and beyond.
Achievement on Automatically Simulation Model Calibration to Provide Fit-For Basin 4D Fea Dynamic Drilling Analysis
Authors: Liu B. , Ma J. , Xu Y. P. , Huang Y. S. , Feng F. , Xu G. 
Published: October 2023

Abstract
After years of using 4D simulation for drilling product design and service event root cause analysis, there is a growing demand for an automated workflow that can provide a standardized and efficient model calibration process. This workflow aims to reduce the dependency on manual adjustments, improve the accuracy of simulation inputs, establish a strong correlation between simulation results and field measurements, and enhance drilling performance prediction. To achieve these goals, the auto calibration workflow incorporates various optimization techniques based on the physics and attributes of drilling simulation engines. For instance, grid search is employed to optimize discrete formation descriptions using a library of test rock files, while gradient descent is utilized for the optimization of continuous model parameters. Furthermore, the optimization of certain model parameters is simplified by leveraging special drill state data, thereby reducing the complexity of the overall optimization process. These approaches have significantly improved the performance of optimization, even when dealing with computationally intensive simulations. This paper provides a comprehensive review of the newly developed automated calibration workflow, including the algorithm development and field results. It also discusses the lessons learned from this work and outlines future directions for research and development.
Sand Clean Out With Coiled Tubing and the Use of a Special Sand Clean Out Tool: A Case Study in Depleted Wells in Colombia
Authors: Cortés Caterin Barrera , Sanchez Miguel , Hampson Richard 
Published: October 2023

Abstract
Cleaning sand effectively from horizontal wells with slotted liner, low formation pressure, and lost circulation can be very challenging. This paper begins by examining all the relevant factors to develop a suitable job design and applying it to the given conditions for successfully removing sand from depleted wells in Colombia using Coiled Tubing (CT) and a Special Sand Clean Out tool (SSCOT).
The main considerations for the cleanout of depleted wells will be examined, and the steps required to carry out the correct execution of the well cleaning will be shown, considering the main risks that can occur while carrying out the operation. Post-job evaluation is performed to ensure a successful sand cleanout was achieved.
During cleanout of these types of wells, it is necessary to use tools that create turbulence in conjunction with gelled and foamed fluids to keep the particles suspended without affecting the well's productivity and allowing full access to the target depth. Once the cleanout is complete, placement of screen liners in the producing zones can be carried out successfully, reducing future sand production and recovering the production of these wells that have been shut down for many months, even years, due to sand plugging, affecting productivity of the entire field.
Foamed fluids were used for efficient and effective sand cleanout due to the resulting low hydrostatic pressure that reduces the possibility of lost circulation, its high solids transport capability, and compatibility with the formation fluids. This was combined with carrying out the operation using a Special Sand Clean Out Tool (SSCOT), effectively reducing the probability of sticking the CT and achieving efficient sweep results.
CO2 as a Service (CO2aaS) Advisory and Optimization Contractual Models for Critical Production Assets
Authors: Porciani Daniele , Parrella Ilaria , Lauriola Michele 
Published: October 2023

Based on the existing knowledge and capabilities of rotating equipment and critical energy systems, industry players are developing and implementing solutions for Emissions Monitoring and Optimization ("EM&O") solutions, aiming advanced monitoring and advisory as well as emissions reduction targets within their Environmental, Social and Governance ("ESG") policies (e.g. Oil & Gas Methane Partnership 2.0 – "OGMP 2.0" or the United States Environmental Protection Agency GreenHouse Gas Reporting Program – "GHGRP").
By 2021, compliance markets had an annual trading value of more than $900bn, with the European Union ("EU") Emission Trading System ("ETS") by far the biggest, accounting for about 90 per cent of trading volume and value that year (LSEG Market Research, 2023). Much smaller, voluntary carbon markets, for their part, have seen the value of transactions rise sharply from $520mn in 2020 to $2bn in 2021 (Ecosystem Marketplace, 2023). However, growth has come with implementation challenges with waivers, trade-offs and policy postponements, raising questions over the extent to which these markets are reducing global emissions.
Meanwhile, the EU ETS's policy of giving free allowances to heavy industries as long with other policymakers postponing or providing "carbon waivers", along with what until recently were low and volatile prices, carbon pollution credits and/or taxes have been considered too cheap to incentivise large-scale investments in clean technology and/or to oblige users in adopting "green" technology.
Techno-Economic Assessment of Crude Oil/WaterEmulsion Separation Efficiency
Authors: Aljabrine Mashhor , Fairweather Neil 
Published: October 2023

Abstract
The objective of this study is to conduct a techno-economic assessment to identify the necessary investment for maximizing profitability in existing oil processing facilities. As oil reservoirs transition from primary to end of secondary recovery, many processing facilities face challenges due to an increasing water cut. Despite advancements in oil and gas production separation equipment, these facilities must maintain production at the forecasted capacity, leading to potential capital expenditure.
When the water cut surpasses the typical dehydrator's operating envelope (around 30-40%), additional measures are required to reduce the water content and bring the dehydrator inlet water cut back within its operational range. Typically, the conventional approach involves debottlenecking the wet crude handling system by introducing additional process equipment to decrease the water cut into the dehydrator.
However, this assessment explores an alternative solution by maximizing the utilization of existing production separation traps, such as three-phase separators. The study calculates the actual water separation efficiency and considers installing dual frequency desalting technology to replace the standard dehydrator.
The results of this techno-economic assessment indicate that by optimizing the crude oil separation efficiency, the need for immediate capital expenditure can be deferred. This approach allows existing oil processing facilities to efficiently manage the increasing water cut and maintain profitability without significant upfront investment.
Successful Reduction of GHG Flaring Emissions in South Oman Cluster Using Simple CI Tools
Authors: Mandhari A. , Ramakrishnan P. , Maskari M. , Hadhrami A. , Mihajlov R. , Shukaili A. , Tobi Y. 
Published: October 2023

Abstract
Controlling oil and gas stations effectively to reduce GHG emissions is a crucial step in mitigating the effects of climate change. This study focuses on identifying and applying the strategies available for reducing GHG emissions from the South Oman Sour Cluster. Minimizing flaring attributed to facilities instabilities, leads to flaring, as well as flaring on planned shutdowns and start-ups using six sigma approach and cut down the average flaring by 35% through operational excellence.
Controlled flaring during Shutdowns, start-ups and partial trips of production units, a novel thought of a simple Six-Sigma CI approach. Back pressure control in the chokes of each well, which directly balances/controls the flow line pressure, controls bubbling effect in the TH and NAG and results in better GOR. This phenomenon occurs in many natural and engineered systems. HP separators in Station-H operate at 85 BarG. Well chokes control NAG release. Back pressure control technique is applied to wells in a unique way, which maintains constant pressure in the flow line and optimizes flow of oil and gas from the reservoir.
Project Benefits (During the pilot period from 01/05/2022 to 05/05/2022) lead to Flare reductions in Station-H which reduced flaring during start-ups of the station by 35% taken on an average of 5 days and reduced flaring during any unit trip by 55% with Yearly reduction. Deferment savings of 0.8M $ in each start-up and S/D. back pressure controls applied using chokes, enabled flow optimizations to each well to reduce annual GHG emission by 13 k tone/year of CO2. Compressed sour gas from LP/IP compressors diverted to Gas sweetening units converted in to sweetened gas. If any compressor trips, or S/D well chokes in back pressure control reduce gas feed/ cutoff feed to HP Separators. Back pressure controls abnormal fluid behavior is controlled in tubing head. Under controlled pressure more oil flow occurs, reducing NAG gas flow. This prevents undesired situations like producing more injected gas than crude oil from the oil reservoir. Back pressure control applications directly reduced flaring of NAG and yielded better GOR without major changes in the process. Flaring control and reducing GHG emissions to ZERO is the long-term objective of our team by effective application of CI, six sigma and operation excellence. Flare Gas Recovery projects deploy new technologies to recover gas such as energy transformation and waste heat regeneration in the aim of achieving GOAL ZERO.
Title- Planning and Contract Management Strategies for Successful EPC Project Execution
Authors: Mahajan Aniruddha , Baride Milind 
Published: October 2023

Abstract
EPC Project execution is always a complex task requiring amalgamation of multiple engineering and technical skills along with Project Management excellence. Projects cannot be successfully executed only by the Owner, PMC, and EPC Contractor alone but require vendors, subcontractors, and service providers whose role and performance are key to project success. Successful EPC project execution requires the strategy to onboard the right stakeholders onto the project at the right time in a planned manner during the various execution stages of the project and ensure that they promptly deliver on time, safely as per the technical specifications, within budget as per plan and Contract. Thus, ensuring that every stakeholder delivers as per the plan and the Contract will ensure that an EPC project is successful.
The strategy for Project execution depends on several factors which include amongst others scale and complexity of the project, the business environment, location of project site, general market conditions, availability of skilled engineering and construction resources. Too often the focus is on getting the Project execution right with strategies focused on the above drivers without focusing on the underlying people constituting the project team who are going to execute the strategy and the project.
Projects are temporary endeavors with a definite beginning and end to achieve specific goals. Projects assemble large groups of highly skilled cross functional resources on a temporary basis to deliver project goals and the outcome of the project will depend on how this temporary team functions, collaborates and delivers. This is the biggest internal challenge of the Project team, one which can make or break the project success.