bluuebunny/crossref_metadata_2025_split huggingface dataset:
Achieving Zero Lost Time Injury in a Refinery: A Practical Approach
Authors: Robert Eretoru , Junaid Camilla , Idris-Idah Kawu , Oyeyele Adebimpe , Olomolaiye Daniel 
Published: August 2022

Abstract
This paper aims to highlight and share some insight on how a modular crude oil refinery operating at 5000bopd capacity delivered refined products with zero LTI. The intention is to pass knowledge to upcoming modular refineries as projections from the Ministry of Petroleum Resources indicate that many more will spring up within the next few years. The refinery came live in November 2020 and was tasked with ensuring optimum production in a safe working environment. Since then, it has gone on to safely refine over one million barrels of crude oil
In the Oil and Gas industry, safety is a crucial determinant of the overall success of a facility’s operations. Refineries have even greater responsibilities, given that there is the presence of highly volatile and flammable hydrocarbons within the facility, and personnel having consistent interactions with these liquids pose a huge danger. Achieving zero LTI implies that in the period under review, no incidents occurred that prevented the continuity of the core activities of the workplace, no productive work time was lost due to injuries to an employee and as such, is a key indicator in measuring safety performance, hence its adoption
The steps taken to minimize and eliminate risks peculiar to the refinery were discussed, with these taking the form of engineering controls, policies and procedures. It is interesting to note that in the operation of a refinery, the areas that are most vulnerable to accidents are outside the core process areas. The array of process control systems, alarms, and fail-safes keep the system within operational limits. The systems involved in the storage and offloading of hydrocarbon products, however, handle more volumes of hydrocarbon, with higher frequency and is prone to human error. This work is a summarised document that contains proactive safety-inclined solutions and lessons learned along the way, hopefully translating into increased productivity and safety within the downstream space.
Effective Asset/Portfolio Management: NAPIMS Perspective
Authors: Nnakenyi Norbert , Amos Simon Olushola , Abegunde Mobolaji , Ayo-Dayisi Ibidunni , Anozie Nnabuike , Gari Tayiro , Akintade Olusemola , Musa Aminu , Ibrahim Habeeb 
Published: August 2022

Abstract
NAPIMS is the investment portfolio management arm of the NNPC that has been entrusted with investments of the federal government of Nigeria in the oil and gas sector. In alignment with best international practices, NAPIMS adopted an efficient asset-based management organizational structure to monitor the true performance of the entire assets within its portfolio.
Having an overview of all assets serves as a roadmap/link to obtaining vital background information about legacy performance as well as plans and strategies. Over the years, NAPIMS had a less structured asset overview for producing and non-producing assets thereby, encumbering information access for budgetary and budget performance tasks.
The deployed methodology ensures that investments meet the long- and short-term financial objectives and risk tolerance of NNPC and Nigeria at large.
This work bridged the performance gap between producing and non-producing assets by delineating important parameters for that influence asset portfolio management. This project also encompasses useful technical, commercial, planning, and financial parameters from sub-sections within an asset group. The developed and implemented solution offers good flexibility by providing every essential and minute detail that can help an asset manager to deep dive into the historical and current performance. It further warehouses the plans for future growth, expansion, and optimizations towards greater profitability.
Formulation of Bio-Surfactant Augmented with Nanoparticles for Enhanced Oil Recovery
Authors: Ihekoronye Kingsley Kelechi 
Published: August 2022

Abstract
In this study, a novel concept of enhanced oil recovery was explored to improve oil recovery in the Niger Delta oil fields. Experimental investigation of bio-surfactant augmented with nanoparticles was evaluated to determine the influence of the nanoparticles on enhanced oil recovery. Bio-surfactant derived from yellow oleander seeds oil was formulated. Nanoparticles such as silicon oxide, titanium oxide, aluminum oxide and magnesium oxide was used as a displacing fluid due to its ability to alter the rock wettability (oil-wet to water-wet) and interfacial tension reduction of the oil/water interface of the rock property. Core-flooding experiment was conducted using four Berea sandstone cores sample obtained from the Niger Delta oil field to investigate the suitability of the nanoparticles and bio-surfactant in enhanced oil recovery process. The results of this study shows that nanofluid flooding with silicon oxide, titanium oxide, aluminum oxide and magnesium oxide had oil recoveries of 43.72%, 45.76%, 46.12%, and 47.07%, 42.41%, 45.00%, 47.02% and 48.10%, 46.10%, 47.31%, 50.26 % and 51.70%, 40.31%, 41.75%, 44.43% and 45.00% respectively. However, nanoparticles augmented with Bio-surfactant had oil recoveries of 46.20%, 48.08%, 52.00% and 53.31%, 45.61 %, 49.51 %, 50.87% and 51.46%, 47.26 %, 48.90%, 51.20% and 52.90%, 43.70%, 46.01%, 47.52% and 48.21% respectively at different concentrations of nanoparticles and bio-surfactant. The result from this study shows that nanoparticles with bio-surfactant improve oil recovery via interfacial tension reduction and wettability change.
Effectiveness of Mangifera Indica Peels for Heavy Metal Adsorption in the Treatment of Produced Water from Niger-Delta Oilfields
Authors: Ajani Mofopefoluwa A. , Isehunwa Sunday O. 
Published: August 2022

Abstract
Produced water usually contains contaminants such as hydrocarbon fractions, heavy metals, corrosion inhibitors, etc. which are potentially harmful to the environment. Produced water has to be treated to conform to regulatory standards. Treatment techniques that are both robust and cost-effective need to be developed to increase the economic viability of produced water treatment. This research evaluates the effectiveness of mango peels as bio-adsorbents in the treatment of produced water and the effectiveness of modifications made to the mango peels.
Produced water samples were obtained from Niger Delta and analysed for heavy metals using atomic absorption spectrophotometry (AAS).
In this study, mango peels were washed with distilled water, sun-dried and oven-dried at 80°C. The adsorbent was pulverized and sieved (212 μm). Three batches of adsorbent were prepared: unmodified, 0.2 mol/L NaOH treated and 0.5 mol/L NaOH treated mango peels. Samples were treated with individual batches of adsorbent for up to six hours. Treated samples were analysed with AAS. The adsorption capacity, as well as the removal efficiency, were also determined. Adsorption was assessed using the Langmuir and Freundlich models.
For the 0.2 mol/L NaOH adsorbent treatment, the removal efficiency for the metal concentrations (Ni, Pb, Fe, Mn, Cu, and Zn) were found to be 58.33%, 100.00%, 95.00%, 75.00%, 56.00% and 98.67% respectively, while the removal in 0.5 mol/L NaOH adsorbent treatment for the heavy metals were 95.83%, 100.00%, 93.00%, 90.79%, 68.00%, 97.35% respectively.
The unmodified mango peels proved to be ineffective because the metallic concentration in the produced water increased after treatment (except for Lead and Copper). The modified variants proved to be effective as they reduced metallic concentration. The 0.5M NaOH modified variant outperformed the 0.2M NaOH modified variant. This shows that pH and contact time affect the adsorption process.
Corrosivity of Niger Delta Environment for Corrosion Control and Management
Authors: Amadi Azubuike , Ajienka Joseph , Akaranta Onyewuchi 
Published: August 2022

Abstract
It is difficult to simply bury a pipeline beneath the ground without facing corrosion challenges, yet it is important to do so for both the search for crude during drilling and pipe laying for oil and gas transportation. The oil and gas business has lost millions of dollars owing to corroded pipes, making it vital to evaluate the severity of environmental corrosion before making investment decisions. The Niger Delta, which is a hub of oil and gas activity in Nigeria, was the focus of this research. This research aims to reduce the impact of environmental corrosion on buried oil and gas assets by creating a corrosion map and model tailored to the environment in order to identify the level of corrosion severity at various points. 93-points soil resistivity data were collected using Vertical Electric Sounding (VES) and the Werner method, while average pH data from Rivers, Bayelsa, and Delta States were gathered from research within the Niger Delta. The extent of corrosivity in the environment was estimated using both the soil resistivity data and pH data. As an enhancement over the traditional method of employing ranges, a model was developed to determine the exact corrosion severity of the environment based on its soil resistivity. In addition, MATLAB was used to create a 3D planar curve and a map that could be used to quickly evaluate the corrosion severity of regions in the Niger Delta. This research paved the way for the continued development of corrosion severity maps unique to distinct oil and gas activity regions, as well as advancements in asset management for buried oil and gas assets.
Application of Genetic Algorithm on Data Driven Models for Optimized ROP Prediction
Authors: Duru David , Kerunwa Anthony , Odo Jude 
Published: August 2022

Abstract
The demand for cost-effective drilling operations in oil and gas exploration is ever growing. One of the important aspects to tackling the aforementioned difficulty is determining the optimal rate of penetration (ROP) of the drill bit. The most important optimization objective is to achieve a high optimal rate of penetration in safe and stable drilling conditions. Several machine learning models have been developed to predict ROP, however, there have been few studies that consider the different optimization algorithms needed to optimize the conventional developed models other than the conventional grid search and random search techniques. Genetic algorithm (GA) has gained much attention as methods of optimizing the predictions of machine learning algorithms in different fields of study. In this study, GA optimization algorithm was implemented to optimize 5 machine learning algorithms: Linear Regression, Decision Tree, Support Vector Machine, Random Forest, and Multilayer Perceptron algorithm while using torque, weight on bit, surface RPM, mud flow, pump pressure, downhole temperature and pressure, etc, as input parameters. Three scenarios were analyzed using a train-test split ratio of 70-30, 80-20 and 85-15 percent on all the developed models. The results from the comparative study of all models developed shows that the implementation of the GA optimization algorithms increased the individual ROP models, with the multilayer perceptron model having the highest coefficient of determination of 0.989% after GA optimization.
Hybridization of Optimized Supervised Machine Learning Algorithms for Effective Lithology
Authors: Aniyom Ebenezer , Chikwe Anthony , Odo Jude 
Published: August 2022

Abstract
Lithology identification is an important aspect in reservoir characterization with one of its main purpose of well planning and drilling activities. A faster and more effective lithology identification could be obtained from an ensemble of optimized models using voting classifiers. In this study, a voting classifier machine learning model was developed to predict the lithology of different lithologies using an assembly of different classification algorithms: Support Vector Machine (SVM), Logistic Regression, Random Forest Classifier, K-Nearest Neighbor, and Multilayer Perceptron (MLP) models. The result of the comparative analysis shows that the implementation of the voting classifier model helped to increase the prediction performance by 1.50% compared to the individual models. Despite a small significance at deployment in real scenario it improves the chances of classifying the lithology.
OML-ZZZ: Water Production Forecasting Improvement
Authors: Agbehi Raphael , Aboaja Ugochukwu , Osho Rotimi 
Published: August 2022

Abstract
Reliable production forecasting of all fluid streams involved in hydrocarbon production has remained a perennial problem in the oil and gas industry. This paper presents the methodology and results of an improvement to the water forecasting approach adopted in the management of all the producing fields and reservoirs of OML-ZZZ located in the Niger Delta area of Nigeria. The main objective of our study was to identify and evaluate a means of achieving water/liquid forecast that is representative of field observed trends – a key input for the sizing of planned water dehydration facilities for our fields. Our study made use of an integrated production forecasting solution model with the associated engineering and geoscience data, which optimizes on oil production while forecasting the other fluid streams subject to defined system constraints. Improvement in water forecast was achieved through a review of the abandonment conditions of quit wells which have already reached their abandonment as analogues for producing wells being forecasted. Based on the review, we identified and applied recommended tranches of BSW conditions which have enabled better and more realistic forecasts of gross liquid and water production. The benefits of these improved forecasts include an increase in oil volumes and proper equipment/facilities sizing among others.
Reducing NPT Amidst Fluctuating Crude Oil Prices: Using Data Analysis to Investigate Well Construction Cost
Authors: Ajayi Olawale Isaac , Kehinde Sodiq Adejuwon , Akpan Unwono James , Odesa David Emudiaga 
Published: August 2022

Abstract
During drilling operations, one of the key parameters keenly monitored and measured is the Non-Productive Time (NPT). It is usually desired to be kept as minimal as possible due to its significant contribution to the entire well construction cost. In some instances, some of the factors responsible cannot be controlled such as bad weather conditions or occurrence of natural disasters. However, industry experience shows that a significant chunk of most NPT recorded can be avoided and mitigated with adequate planning, monitoring and prompt decision-making. In order to ensure sustainable oil production amidst the present economic situation of fluctuating crude oil prices occasioned by the imminent energy transition and other related factors, the costs associated with development and production of hydrocarbon assets will require prudent management by eliminating or reducing NPTs. This paper aims to illustrate some of the best in-class operational procedures and actions undertaken by the drilling operations team of a producing company for significant reduction of NPT spanning across seven (7) wells in two (2) of its producing fields. Information from structured daily operations reports were extracted and analyzed with significant focus on the time sheets and contributing factors to Non-Productive Time. Further attempts were made to identify the major contributors and the most efficient processes to eliminate their occurrences. The analysis shows an average of about thirteen percent from the first well drilled in 2018 to the most recent one drilled in 2021. This translates to about USD5.4 million in NPT cost equivalent over the span of the seven (7) wells. The prevalent drilling operational challenges were found to be related to host community issues, location preparation, statutory regulatory compliance issues, logistics, weather conditions, crew competency, well-bore instability, and most prevalently rig equipment failures etc. The data analysis showed a consistent decrease in NPTs for these factors, primarily due to deliberate and concise project planning and execution. The results from these analyses can therefore be used as a framework to improve current drilling practices, in order to achieve significant well construction cost savings and further support the need for sustainable oil production. However, it is important to ensure quality data gathering and structure by insisting on identifying and recording all the NPT-related issues. This will allow prompt forecasting of drilling operational challenges as well as proactively taking concrete steps to mitigating them.
Paraffin Inhibition in the Tubing of a Gas-Lifted Production Well Using Pre-Conditioned High Temperature Gas
Authors: Nwankwo Kenechukwu 
Published: August 2022

Abstract
Gas lift technology involves the introduction of gas in the tubing to improve vertical lift performance and over all well productivity. However, when wax is deposited in the tubing, the pressure drop across tubing is increased and vertical lift performance is adversely impacted. This paper reviews the performance of two wells known to have wax deposition issues leading to sub-optimal production, thus necessitating intermittent paraffin inhibition /hot oiling which have associated costs.
A Fluid Thermodynamics model which demonstrated that production from the two wells can be optimized by gas lifting wells at points deeper in the tubing than the nucleating points at a threshold gas lift temperature was developed. The minimum gas lift temperature at any given pressure required to attain this flow assurance solution was simulated from the model developed. The model illustrates that a thermodynamic state can be attained without the use of an inline heater. This was due to the high discharge of thermal energy from the lift gas supplied from the gas lift manifold.
Results from model application to the two case study wells showed improvement of flow rates from sub-optimal values to steady rates of total increments of about 1,000 Barrels of Oil Per Day. In addition, wax deposition ceased as confirmed from the laboratory re-estimation of the Wax Appearance Temperature (WAT) of the wellbore fluids. This model application eliminated yearly remediation operations such as hot oiling operations that was in place to manage and ensure that the wells produced continually, resulting in an annual cost saving of about $30,000 per well. This Thermal inhibition method can be applied in all wax producers to eliminate or reduce wax in tubing and hence the flow line.
2010 Gulf of Mexico Macondo Oil Spill Disaster: HACCP Lessons for Nigeria's Gulf of Guinea
Authors: Theophilus Tubi O. , Falode Olugbenga , Ogunshe Adenike A.O. 
Published: August 2022

Abstract
Dealing with potentially vast and serious environmental incidents has remained a challenge for the Oil and Gas Industry, thus, the aftermath of April 20, 2010, Macondo disaster, deserves a holistic overview of events responsible for, or associated with, the disaster. The study adopted and adapted the HACCP analysis and drew lessons by not only identifying and tracing the immediate and remote causes of the spill but also making appropriate recommendations on prevention and remediation measures to be adopted at similar operating points in the Gulf of Guinea area, like Shell's Bonga FPSO facility and Chevron's Agbami.
Using detailed extrapolation as a basis for the establishment of material conditionalities and similarities existing between the Gulf of Mexico and the Gulf of Guinea, the study was conducted with the aid of an extensive and exhaustive review of literature, technical reports, and other de-classified materials to determine, amongst other things, the how, why and lessons learned. The results show that there are still technological, legal, and administrative lapses in our jurisdiction, causing shortcomings in the applicable administration of rules, regulations, and enforcement procedures in the Oil and Gas sector, which has been and is still being exploited negatively by industry players.
Hazard Analyses Critical Control Points addressed particularly include, causes of explosions, nature of fire, loss of well control, blowout, vessel sinking, casualties, modes of evacuation, vessel safety systems, oil spillage, environmental damages, systems deficiencies, maintenance of electrical equipment, gas alarms and automatic/emergency shutdown systems, the inadequacy of crew blast protection equipment barrier, inadequate intractable command, and control hands-off, lack of requisite training for personnel on emergency preparedness, to shut down engines and disconnect, risk-based decisions, abilities to prevent or limit the magnitude of the disaster.
The study concluded that an immediate review of some identified outdated rules and operational guidelines of the DPR be undertaken, namely: procedure guide for the construction and maintenance of fixed offshore platforms; procedure guide for construction & maintenance of surface production facilities; flexible pipes, SCR, and mooring chain systems. requirements for the maintenance and inspection of flexible pipes, SCR, and mooring chain systems; operation & maintenance of pipelines. guidelines etc. Adding more pre-installed blowout preventer (BoP) systems per rig/drill line, as well as call for a review of proposed PIB, EGASPIN 2018, and a further strengthening of NOSDRA.
Driving Project Efficiency and Cost Control in Nigeria's Oil and Gas Industry
Authors: Atolagbe Emmanuel , Mohammed Sani 
Published: August 2022

Abstract
Oil and gas companies continue to contend with numerous existential challenges that are exerting pressure on their activities. Some of the challenges includes the rise in alternative and renewable energy, persistent talent challenge, increase in supply chain complexity, price volatility and growing competitive pressure (EIA, 2020). The need to respond effectively to these challenges has made cost control a strategic imperative and competitive necessity. Cost control should be applied as a strategic lever for improving project efficiency, influencing growth and boosting profitability through conscious and proactive approaches, rather than using cost management as a defensive tool (Aguilar and Ittner, 2018). New innovations like digitization, advance analytics and artificial intelligence provide potential solutions capable of addressing these problems (Bohari, 2020). These innovations can easily be implemented and enable rapid transformation of the industry.
Cost control and project management initiatives have been implemented across most of the oil companies to weather the impact of rising cost and the low oil price. It was realized that having the right system in place, deploying modern technology, effective data collection and analysis, process reengineering, and automation are imperatives for driving cost reduction, capital efficiency and delivering competitive projects (Aguilar and Ittner, 2018). For instance, the leadership of one of the oil companies mandated the application of cost control and effective project management to well projects cost (circa $300-500mln annually). A combination of programs, innovations and practices were implemented between 2019 and 2021 and the control process was strengthened which resulted in savings of $20mln+ per annum year-on-year on drilling and wells related cost. Additionally, cost overruns were reduced and cost recovery from the JV partners improved due to better cost transparency and efficient cost management.
This paper aims at contributing to the quality of cost management decisions, and improved planning and performance by exploring the impacts of technological disruption on cost control and assessing how it can drive efficiency and improve performance in oil and gas companies in Nigeria through a review of existing literature on the subject.