bluuebunny/crossref_metadata_2025_split huggingface dataset:
ESP Deployment Cable Demonstrates Resilience in the Face of Corrosion Challenges in Harsh Downhole Environments
Authors: Al Munif E. H. , Banjar H. M. , Ejim C. E. , Xiao J. 
Published: October 2023

Abstract
Electric Submersible Pumps (ESPs) face significant corrosion challenges in downhole environments due to high temperatures, pressures, and presence of corrosive fluids. These conditions can cause material degradation and severe damage, reducing equipment lifespan and impairing its performance. A Cable Deployed ESP (CDESP) is an alternative ESP deployment method, where the ESP is deployed by a specially designed cable with hydrogen sulfide (H2S)-resistant properties.
This paper shares lessons learnt from three different CDESP installations. It discusses the findings and results of dismantling, inspection, and testing of the encapsulated cable, as well as various CDESP components, including the pump, motor, connector assembly, seal, and sensor. The encapsulated cable was specifically designed for utilization in production environments with high H2S. The paper aims to provide valuable information on the performance and durability of CDESP components in downhole environments with corrosive fluids, high temperatures, and pressures.
The metal encapsulated power cable played a pivotal role in the CDESP system by offering outstanding shielding against H2S attacks and enabling a smooth outer diameter that could be easily grasped and sealed around. Furthermore, the cable was able to withstand harsh H2S environments with concentrations of up to 15mol% and chloride levels exceeding 150,000 ppm, proven from the lab and from the fields. While the developed cable proved to be robust and effective in harsh downhole conditions with high H2S concentration over a long period of time, the study findings indicate that other equipment components need to be improved to withstand corrosion. In all installations, signs of corrosion were observed on other system components such as thrust bearings and runners. Corrosion can cause blockages, increase friction, reduce system efficiency, and result in electrical or mechanical failures. Electrical failures include insulation failure on the cable, connectors and motor windings, while mechanical failures include bearings failure, broken shafts, pinholes and impellers damages. As a preventive measure to mitigate this corrosion from occurring in the seal and motor sections, an H2S scavenger (copper tube) can be installed to all seal chambers. In addition, pressure testing procedures during installation should be developed to enhance reliability.
Overall, this paper highlights the effectiveness of the developed cable and the need for further improvements in other components to ensure long-term reliability and performance of downhole equipment.
ESP Design Improvements Associated with Downhole Slotted Gravitational Filter and Downhole Chemical Treatment Prolong ESPs Run Life in Western Desert of Egypt: Case Study
Authors: Salah Ahmed , Sabaa Ahmed , Elhaleem A. Samir Abd , Medhat Ahmed , Diaa Ahmed , Abu-hozifa Osama 
Published: October 2023

Abstract
Electrical submersible pumps (ESPs) have become the most efficient and reliable artificial-lift method worldwide. One of the most common causes of premature failure in ESP systems is erosion or clogging from sand and solids in the reservoir fluids. These solids generate wear in pump stages, reduce its lifting efficiency and increase frequency of well interventions. Consequently, these ESP failures require reliable solutions to enhance the performance and prolong the run life of the ESP system.
In subject field inside the Western Desert of Egypt, several wells were experiencing pre-mature pump failures because of plugging, sand erosion on pump stages, and broken shafts. Five previous ESPs had been run in three offset wells, all of them had failed after average run life of 150 days. A detailed discussion with a technology provider and reference case studies come up with an integrated approach utilizing ESP Design improvements including Reliable Abrasion-Resistant Pumps and upgraded shaft material. The ESP system also incorporates a downhole slotted gravitational sand filter and continuous downhole chemical injection.
The slotted gravitational Sand filter is an innovative solution to take control of downhole sand problems utilizing gravitational force and filtration process. It prevents particles 100 microns and larger in size from entering and damaging the ESP system. In SWM field, Hydrocarbon recovery is mainly from one deep reservoir characterized by a high-pressure high-temperature (HPHT) environment at depths around 16000 ft, average pressure of nearly 6400 psi, temperature reaching 310 F, and considerable amounts of CO2 and H2S. The pump was set at 10000 ft to produce 2000 BPD with wellhead pressure not less than 1000 psi. In spite of, these challenging operating conditions and high withdrawal requirements, the newly designed system was capable to maintain stable ESP performance in two offset wells for more than 14 months and still ESPs are running. This solution showed significant improvement in overall system reliability and performance. Specifically, it helped to economically produce from the wells, reduce deferred production and downtime resulting from frequent pump failures, and maximize their recoverable reserves. In addition, it increased the capability of being replicated in other wells with high sand production.
This paper will provide a detailed completion design process to create a robust ESP system that fits with challenging wellbore conditions in which sand production and erosion are growing concerns. This study starts from initial installations, subsequent well interventions, equipment Dismantle Inspection and Failure Analysis (DIFA), ESP configuration enhancements, and finally reaches field application performance data in which the new completion design was successfully implemented to extend ESP run life.
ESP Cable Deployment has Induced a New Paradigm in UAE to Turn the ESP Business into Rigless Operation, Presenting a Cost Efficient and Faster Application
Authors: Guzman Rodrigo , Hashmi Zahra Faisal Al , Ilyasov Ruslan , Sonbaty Tarek Mohamed El , Gupta Sanchay , Aguilar Hector , Martins Azubuike , Ofodile Onyebuchi , Cardozo Padron Jose 
Published: October 2023

Abstract
The implementation of the first pilot of the fully rigless ESP deployment in the UAE (United Arab Emirates), has successfully overcome the challenges of well availability and maintainability when using artificial lift systems. The application achieved the production potential of a standard ESP and completely replaced the requirement for a rig during its deployment.
This enhanced ESP deployment is shifting the paradigm associated with ESP and rig intervention and is establishing new opportunities for the artificial lift industry. Cable deployment ESP is the only full rig-less technique allowing to complete the deployment in smaller tubing size (2 7/8" and 3 ½") compared to other kind of ESP semi-rigless deployment as coiled tubing and slickline, which are normally limited to a 4.5" production tubing and initial rig interventions.
The time and resources required for rig intervention were significantly reduced. This resulted in reducing HSE risks, reducing the and the carbon footprint by more than 50%, compared to standard rig-based ESP operations.
With the aim of reducing the number of inactive wells and maximizing return on investment, while also reducing the work-over cost of oil ESP wells, the cable deployment rigless ESP was introduced to eliminate the rig costs associated with the ESP work-over costs - which represent 75-85% of total costs for an onshore ESP completion. Additionally, this approach reduced the failed ESP recovery time from 200 days (mainly waiting to allocate slot in DWS (Drilling and Workover Schedule) to 30 days, which decreased deferred production by 85%. Furthermore, this technology has proved to be an efficient tool to reduce inactive wells percentage, as it can be used as a temporary solution for gas lift wells waiting on availability of surface facilities, which typically could take five years.
The payback of rig-less ESP is 15 days, versus payback of 38.6 days for a rig-based solution, it also avoids an average production deferment of 275K oil barrel per well/year and drastically decreases the number of inactive wells, supporting operations teams to sustain production quotas.
Based on the trial results, the cable deployed rigless ESP has created business value through the following: Successfully re-activate production in less than 1.5 days.Proven success of rig-less application (installing and pulling activities).Production delivered after 2 hours of deployment (as per ESP design/model).Reduction footprint by 60% (compared rig-based ESP)Stable operation conditions observed and achieved proposed runlife of 360 days compliant with HSE 100%.
Navigating Net Zero – The Emerging Role of the National Energy Company
Authors: Markouizou Virginia 
Published: October 2023

Executive Summary
In this session we will aim to present a possible pathway for National Energy Companies (NECs) to promote country inward investment that supports climate resilience, a managed transition from hydrocarbon overdependence and net zero goals. We will aim to address how NECs, in close cooperation with their respective Ministry, can develop country analytics that lead to a comprehensive national energy plan that prioritizes climate resilience, renewable energy sources and energy efficiency measures.
We will show how countries such as Namibia understood that they have a once-in-a-generation opportunity to significantly reduce their emissions by leveraging their natural resources to attract muchneeded foreign direct investment and how they moved decisively to develop a portfolio of complimentary infrastructure projects, with a vision to create a hub of renewable assets and effectively transforming their country.
The complexities of the different roles that the NECs have to play today are well recognized. They need to protect core energy assets, revenues and existing cash flows, create jobs and ensure energy security. The NECs are also expected to confidently step towards a net zero and sustainable future on behalf of their country. Global governments expect NECs to deliver emissions reduction at a country level, the practical steps for energy transition and, to a large extent, the delivery of the National Determined Contribution.
In this current environment, NECs around the world are starting to pivot towards climate resilience and renewable energy investments. The NECs must compete for access to capital and participation in the race for a "just" transition. In 2019, the IMF issued a report calling for more transparency in the management and governance of National Oil Companies (NOC) – calling them the "hidden economic giants". Remaining opaque or "hidden" is no longer an option. In a world that demands transparency which addresses ESG and sustainability commitments, capital markets expect consistent reporting. This is a big task for organizations which still face major shortcomings on their reporting practices, and in some cases, have no history of environmental reporting.
To complicate matters further, there is currently no universal standard for external reporting of environmental data, so it is for the individual NECs to determine which data analytics and insights will allow access to energy transition finance at competitive rates. There is general agreement though that data driven investment decision making that allows for transparency, stakeholder engagement and private/public sector collaboration is now needed more than ever for capital allocation and access.
In this context we will aim to present how NECs can use historic static and dynamic operational data analytics to understand and address risk and opportunity and successfully develop their energy investment decision frameworks.
Enabling Autonomous Well Optimization by Applications of Edge Gateway Devices & Advanced Analytics
Authors: Kumar Manish , Varma Nakul , Rao Manjunath , Chandak Ravi , Jadhav Sujit , Sharma Himshella , Singhal Joy , Ranjan Amit , Chauhan Shailesh , Bohra Avinash , Patni Atul 
Published: October 2023

Abstract
Data monitoring in a big oil field without any digital platform is a challenging task but it is critical for ALS monitoring and optimization. In sucker rod pumping wells, real time dyna card collection and analyzation is very important for understanding downhole pump behavior and system health. Manual dyna card collection twice a week for ~47 horizontal wells is very low. Real time dyna card requires atleast 256 data points per minute frequency. Its analysis is very effective to optimize well production and increase the pump life and rod run life. The lack of real time monitoring resulted in well downtime and associated production loss. The combination of IOT, Cloud Computing and Machine learning implementation shifted our approach from reactive to proactive which assisted in ALS Optimization and reduced production loss.
The data is transmitted to Se Suite Central, a web based Descisison Support System hosted on cloud. Since thousands of dynacards are generated in a day, therefore the algorithm was made with automated card classification using computer driven pattern recognition techniques. The real time data is used for analysis including basic statistics and machine learning algorithms to classify thousands of dynacards every day. The pump signatures were identified using machine learning libraries and categorized. Several informative dashboards are developed which provided quick analysis of ALS performance, a few of them are -
Well Operational Status Dyna cards Interpretation module SRP parameters visualization Machine Learning model calibration module Pump Performance Statistics
After collection of enough data and creation of analytical dashboards using domain knowledge, the gained insights were used for ALS optimization.
Smart Alarms were generated using statistics and machine learning settings by the system which gave alerts by e-mail if an abnormal behavior or erratic dyna-cards were identified. This helped in reduction of well downtime in some events which were treated instinctively before. The integration of domain knowledge and digitalization enabled to take informed and effective decisions. This project supported in effectively managing a complete asset of more than 47 wells remotely with limited resources. This set up has capably run low PI wells intermittently, which has saved power consumption to run the surface pumping units. This digitalization plan has prevented many pump & rods failures, resulting in saving numerous workover jobs and well downtime.
Machine Learning Application of Core and Log Prediction in Various Depositional Environment Case Studies
Authors: Shah Jamari Mohd , Masoudi Rahim , Zulkifli Nur Fatihah M , Sansudin Salmi , Fadhil M Imran M 
Published: October 2023

Abstract
Conventional methods of acquiring log and core often exposes project owners to high cost and time-consuming operation. Other than that, massive data availability in different platforms are also persistent issue waiting to be resolved. Artificial Intelligent module of well log artificial intelligent prediction module named Enhanced Resource Monetization Artificial Intelligent (ERMAI) and physical core artificial intelligent prediction module named Core Artificial Intelligent (COREAI) are developed to eliminate expensive operation, factor out human biasness, enable prediction of core data and log data at any depth and all data are kept in structural corporate database.
Overall approach presents innovation and agile technologies that integrate data management, data quality assessment and predictive machine learning to maximize the company asset value using existing core and well log data. The development of machine learning algorithms identifies potential outliers, benchmark the valuable data against the current industry standards, increases the confidence in data quality and avoids augmented error in predicting reservoir properties. For core prediction using CatBoost algorithm machine learning methods by combining digital raw data with core photo. And for log prediction using random forest assemble learning methods which using certain training wells for massive prediction.
Life Cycle Cost Assessment for Digitalization Project Implementation in an E&P Company
Authors: Mishra Nikita , Saraf Anup 
Published: October 2023

The main objective of this manuscript is to devise an objective, scientific and empirical tool for assessing the ‘life cycle cost’ of any digitalization project in an Exploration and Production (E&P) Company vise-a-vie its ‘projected benefits’. This provides a ready-made empirically proven tool for the CIO or Project Manager of the E&P Company to decide on the ‘financial model’ for an upcoming digital project during the conceptualization stage when there's a long debate amidst the project team or the user indenting group regarding CAPEX or OPEX or Hybrid Model for the digital project implementation. With the advent of cloud platform and SaaS platform, various exciting avenues have opened up for companies to implement digitalization solution in OPEX model where the upfront investment is very less. Moreover, most of the R&D in this domain around the industry is keeping cloud servers in mind resulting in breakthrough digitalization innovation opportunities for E&P companies at a very nominal cost. However, there is a different narrative as well which signifies the advantages of owning the system(s). This manuscript has tried to settle this long-standing debate.
This manuscript develops a table with a total scoring out of 100 marks with weighted average given to the different factors or parameters. This is a multi-dimensional scoring system developed keeping various factors and scenarios in mind. This also takes into factorization whether the digitalization project under discussion is of transformational nature or incremental nature. This also has a scenario to pick from exploration / drilling / reservoir/well/production/pipeline or complete Digital oilfield project scenario which leads to a different customized scoring pattern. The user has to select various scenarios and factors in the checklist of two pages according to which the scoring pattern is decided for them leading to a customized scoring, hence decision-making tool for them. Apart from the checklist, user has to enter the estimated project cost over lifecycle and range of gain in the checklist too.
First Application of Biogenic Fibres in a Reservoir Drilling Fluid to Enable Safe Drilling and Data Acquisition Across a Depleted, Highly Laminated, Carbonate Reservoir With Heterogenous Characteristics
Authors: Jeughale R. , Khan R. N. , Andrews K. H. , Mendez F. A. , Nakano S. , Toki T. , Alzaabi M. A. , Klungtvedt K. R. , Sarap G. , Meki Z. , Gupta K. , Vallejo A. V. , Ramnarine N. , Nofal S. F. , Alzaabi A. Y. 
Published: October 2023

Abstract
Drilling and completion operations across mature reservoirs are challenging due to high overbalance pressure and become even more so when extended static time is required to satisfy data acquisition requirements. A major Operator in the UAE typically drills challenging 6-inch horizontal drains which cross several heterogenous layers with pore pressure requirements varying from equivalent mud weights of 14.5 ppg to as low as 6.0 ppg across the exposed reservoirs.
With increasing data collection requirements there was a high incidence of stuck pipe events during Modular Dynamics Tester (MDT) operations, which led to significant Non-Productive Time (NPT) while attempting to release the stuck pipe. As a short-term mitigation measure additional work was done optimizing the bridging package along with increased sacrificial treatments and monitoring to ensure compliance with the required bridging scheme.
In parallel, a longer-term strategy was initiated to examine alternative fluid systems or products to mitigate against stuck pipe as Well-As aids for releasing stuck pipe. This paper presents the methodology for the design and field validation of an engineered Reservoir Drilling Fluid (RDF) solution with a thin cohesive filter cake and minimal pore pressure transmission characteristics to achieve well objectives.
Leveraging Carbon Market Mechanism to Achieve De-Carbonization Targets
Authors: Al Mazrouei Shayma , Aggarwal Dinesh Kumar , Ganesan Suresh , Ramachandran Kumaravel 
Published: October 2023

Abstract
ADNOC is committed to achieve 25% reduction of GHG emissions by 2030. The biggest challenge however remains the financial implications of implementing de-carbonization measures. Company has successfully registered one of its "36-inch 52km Pipeline Network Flare Avoidance Greenhouse Gas (GHG) Reduction Project" under the Under the European Fuel Quality Directive (FQD) Upstream Emission Reduction (UER) scheme to generate Carbon Credits, equivalent to amount of flare gas avoided. The process involved: Project identification and development of Project Design Document.Calculation of Upstream Emission Reduction based on daily volume of HP and RG gas diverted and respective calorific values,Third party validation and verification.Transaction of verified Carbon Credits in the international market.
A part of the carbon credits accumulated were traded in the international market to realize carbon revenue. Success of this program complemented Company’s de-carbonization efforts as a clear demonstration of realizing the benefits GHG reduction initiatives that will help offsetting a part of de-carbonization costs, making it a win-win situation.
The project supports ADNOC commitment towards achieving GHG emission reduction targets. Success of the project has been the result of remarkable collaboration between various internal and external stakeholders. This effort will stimulate others Operating Sites/Group Companies to implement similar programs, leading to a wider impact towards fighting the climate change challenge.