bluuebunny/crossref_metadata_2025_split huggingface dataset:
Comparative Study on Gas Utilization Patterns among Marginal Field Operators and International Oil Companies (IOCS) in Nigeria
Authors: Udoh Gershom Christopher , Aimikhe Victor Joseph 
Published: August 2024

Abstract
Natural gas is an essential choice of primary energy due to its comparative advantages, such as higher energy efficiency and lower harmful gas emissions when burnt. Consequently, its production and utilization are imperative for sustainable energy and environmental sustainability. In Nigeria, IOCs and marginal field operators play a pivotal role in ensuring the availability of natural gas to end users. However, studies on the gas utilization patterns of these key players are relatively scarce in the published literature. Hence, this study investigated the gas utilization patterns of Nigeria's marginal field operators and international oil companies (IOCS). The Cochran model was used to obtain a minimum representative number of data with a 4% margin of error and a 99% confidence limit. Gas utilization data, including unaccounted-for gas, sales gas, flared gas, re-injected gas, and fuel gas, were obtained from the published data of the Nigerian Extractive Industry Transparency Initiative (NEITI) from 2012 to 2021 (10 years) and used for the analysis. The results of the study showed that both IOCs and marginal operators prioritized gas sales as about half (46 % marginal field operators and 48% IOCs) of their cumulative gas produced was sold to end users. IOCs also prioritized gas reinjection (28%) compared to marginal field operators (3%). In addition, marginal field operators flared 32% of their entire gas produced compared to 7% for the IOCs. Furthermore, the results suggest that within ten years, from 2012 to 2021, Nigeria lost a conservative total of US$ 16.52 billion. US$ 6.69 billion from flared gas and US$ 9.83 billion from unaccounted-for gas. Therefore, more attention should be paid to unaccounted gas, as with flared gas.
A Framework for Introducing Data Analytics and Machine Learning to Petroleum Engineering Undergraduates
Authors: Mosobalaje O. O. , Aku M. A. , Egbe T. I. , Ibeh C. S. , Aderibigbe A. O. , Ogbonna J. A. , Olayemi M. 
Published: August 2024

Abstract
It is the age of data; data is everywhere! Digital transformation of industries is fueling an exponential growth in global datasphere, enabled by advances in data-measuring smart devices, Internet of Things and cloud computing. The oil/gas sector is not left out of the data revolution. A recent report indicated that about 80,000 sensors generate 2 terabytes/day data on an average offshore platform. The need to transform oilfield data into insights for optimal decision-making is opening up career frontiers in petroleum data science. An increase in demand for talents in petroleum data science is in view. In anticipation of this, the Data Science and Engineering Analytics Technical Section of the Society of Petroleum Engineers, African Region is collaborating with the academia, towards producing graduate engineers possessing domain knowledge and data mining skills. As part of the collaboration, we now present a framework for the incorporation of data science education into petroleum engineering undergraduate programs.
In line with Outcome-based Education approach, a set of learning outcomes for a proposed petroleum data analytics and machine learning course is presented, first. These learning outcomes are framed as skills and competencies expected of students at course completion. Thereafter, assessment rubrics and use case examples are mapped to each learning outcome. These rubrics serves as evidential basis for ascertaining that the skills have been acquired. In completing the curriculum design, a sequence of lesson and lab modules are enlisted as contents over which learners must gain mastery in order to meet the criteria of the assessment rubrics. Furthermore, various elements that make up an integrated learning experience are presented. These include open-access learning resources and toolbox, open-access data sources, instructional strategies, capstone project ideas, research prospects, and industry support (mentorship and advisory). The future prospects of this initiative are also discussed. Some elements of this framework, as presented in this paper, are currently being implemented in a quasi-classroom setting; preliminary performance reports are included in this paper.
Use of Borehole Imaging to Improve the Understanding of Near-Wellbore Geological Features in an Exploration Well in Shallow Offshore Nigeria
Authors: Ndokwu C. N. , Okafor R. , Uluyuz S. , Ofi A. , Onwuchekwa N. , Obikudo P. , Ndefo O. , Ogwogho M. 
Published: August 2024

Abstract
Geological information gathering is critical in every exploration well. Such information helps with establishing subsurface models and deciding on the nature of appraisal to be carried out. Borehole imaging is a veritable tool to get information about the near-wellbore geological features of exploration wells. From structural to sedimentological information, borehole images provide important additional understanding of the geology transversed by a wellbore. The aim of this work is to show the geological features interpreted from high resolution borehole images while logging an exploration well in channelized turbidite reservoir in offshore Nigeria, and to show how these features support the depositional environment interpretation from regional studies.
Like most logging processes, the procedure can be divided into three stages – pre-well planning, real-time logging, post-well interpretation. The pre-well planning includes the selection of borehole image logging tool and optimum logging frequency for the tool. The predominantly contrasting subsurface parameter and geological information being sought after helps in borehole image logging tool selection. In addition to tool functionality, the logging speed is a major check during the real-time stage. This helps to ensure the optimum vertical resolution is achieved. Post-well interpretation starts with data quality checking, data processing, geological feature orientation and identification, and other analyses.
The recognition of a depositional environment can be achieved by field observations, formation evaluation of petrophysical logs and cuttings, fossil studies, mineralogical analysis, geochemical analysis, sedimentary facies and paleocurrent analysis. In this study, the main recognition tool is borehole image facies and the features identified include deformed beddings, thin beds, graded beddings, cross-beds, erosional boundaries, mud diapirs and injectites, faults, fractures, and other high-angled features. These are geological features that can be found in turbidites and associated coarse clastic deposits.
Geological feature orientation and pattern recognition is the main ingredient of borehole image interpretation, and this work is a good documentation of features interpreted from borehole image logs acquired in offshore Niger Delta. Through a meticulous analysis of borehole images, this study aims to depict the geological intricacies present in the targeted shallow-water turbidites. Furthermore, it seeks to establish a correlation between the interpretations derived from borehole imaging and other data sources like seismic interpretation and field studies. This work will serve as a good reference for future detailed studies and comes handy for integrated interpretation.
Characterization, Screening and Feasibility Assessment of Depleted Gas Reservoirs and Saline Aquifers for CO2 Storage in Nigeria: A Pilot Case Study
Authors: Nwonodi Chike , Ozoemene Uchechukwu , Umeogu Ifekelunma , Osimobi Jude , Daodu Olugbenga , Amoo Tope , Uche Johnbosco , Emelle Chima 
Published: August 2024

Abstract
Carbon Capture and Storage (CCS) involves capturing carbon dioxide (CO2) emissions from industrial, oil, and gas operations and securely storing them deep underground. By preventing CO2 from entering the atmosphere, CCS helps reduce emissions. It enables permanent, quantifiable, and verifiable CO2 storage in geological formations. As the world transitions to cleaner energy and strives for net-zero targets, focused CCS feasibility studies and strategic implementation are crucial. Energy companies in many countries are already building CCS hubs, although this process requires dedicated effort and time. With the emerging energy transition drive and ever-increasing company and country net zero targets; it has become paramount to set the scene for more focused CCS feasibility study and future implementation. In most countries, energy companies have commenced building CCS hubs. But doing this organically takes years, dedicated efforts, and strategic focus.
To demonstrate potential for pilot development and operation of the CCS project in Nigeria, many depleted gas reservoirs and saline aquifers were subjected to detailed technical screening and feasibility assessment for CO2 storage in depleted gas reservoirs and saline aquifers. Of the 40 reservoirs screened, 3 reservoirs were selected as potential candidates for CO2 storage. Material Balance model and reservoir parameters for the SeaGen field were used to quantify storage capacity, while implementing the material balance calculations, with similar rock properties used to estimate CO2 storage capacity for the depleted reservoirs. PVT properties of the reservoirs and CO2 properties (density and viscosity) at reservoir conditions were used to estimate for the volumetrics estimations.
This paper presents key technical considerations for CO2 storage in depleted gas reservoirs and saline aquifers in Nigeria; including storage capacity characterization, screening criteria, volumetric-based and production-based CO2 storage estimation methodologies as well as voidage modelling workflow in depleted gas reservoirs. It also focused on both the static and dynamic characteristics of the rock that determine the feasibility in Nigeria. Finally, the paper highlights standard screening workflow for selected depleted gas fields and saline aquifers in Niger Delta, and the results of quantitative subsurface storage capacity and Material balance estimations.
Oil Well Development Through Nodal Analysis for Production Optimization: A Software Assisted Approach
Authors: Oluogun Mojeed Olawale , Uzor Emmanuel Chukwudi , Raji Abubakar , Ogiriki Shadrach Olise 
Published: August 2024

Abstract
The study used the nodal analysis method to design a recovery method for an oil well, Well_08_Og, in the Niger Delta. The well's geometry and configuration data were calibrated using PROSPER software, which is used for well design, modeling, and performance calculations. The well has been in production for an extended period and is experiencing depletion due to natural causes. Sensitivity runs were conducted on artificial gas lift to enhance production, increase water cut, maintain production rate within economic limits, and extend the well's lifespan. The well's calibration successfully replicated the well's performance, with pressure drop and flow rate calculations varying by less than 0.02% and 0.9%, respectively. The nodal analysis technique was used to determine the impact of factors such as productivity index, reservoir pressure, water cut, and gas lift on the well's performance. The gas-lift design was successfully performed, and the well's life was extended as it was producing even at a water cut of 95%.
Analysis of Airborne Magnetic Data for Geothermal Prospecting Over Dau, Upper-Benue Trough
Authors: Adeyemi T. O. , Alagbe O. A. , Amusan R. O. 
Published: August 2024

Abstract
The frequent power outage and unstable supply of electricity in Nigeria has affected the economic development of the nation in many areas, hence the need to look for other means of electricity generation such as geothermal energy. The strategic economic importance and availability of data from the study area arouse the interest of the researchers to focus their attention on the area in search of geological features favorable to geothermal exploration in the study area. In this work, the interpretation of the data extracted from the aeromagnetic maps of the study area was carried out using techniques involving Total magnetic intensity, Residual Anomaly, Tilt derivative, Horizontal derivative, Euler Deconvolution, Analytical signal and Geothermal Potential map. Results from analytic signal technique showed that the study area is segmented by faults and fractures. The depth analysis showed the study area being divided into three basic structures, the deep zone ranging between 1.063 to 2.022km, the intermediate zone ranging between 0.093 to 0.224 km and the shallow zone ranging between 0.036 to 0.077km. The generated geothermal potential map for the study area showed that there is high potentiality for geothermal energy in the North-West, West, South, East and North-Eastern part of the study area.
Comparative Reservoir Characterization and Quality Assessment of Two Sand Bodies in the Omoh Field, Onshore Niger Delta
Authors: Oyeniyi I. A. , Olagboye O. M. , Akpan V. 
Published: August 2024

Abstract
The ‘OMOH’ field is located in the onshore coastal swamp depobelt of the Niger Delta Basin. Six wells have been drilled, and seven reservoirs have been identified in the field. The reservoirs of interest reported in this study are named Reservoirs Sand D and Sand F, which were studied by applying well-logs and 3-D seismic data. This study is aimed at determining the comparative heterogeneity, characteristics and quality of two reservoirs by deciphering their performance and deliverability. The heterogeneity, facies distribution, quality and performance of the reservoirs were assessed by applying well logs, 3-D seismic, amplitude maps and petrophysical analysis. The results show that reservoir D has an excellent Net-To-Gross value of 0.84 and a volume of shale value of 0.26. The reservoir has a gross thickness of 478 feet, a good average porosity value of 0.26, and a permeability value of 250.7 mD. This characterized the reservoir as a typical sandstone reservoir with very good porosity and permeability. The results for reservoir F show that it has a low Net-To-Gross value of 0.55 and a volume of shale value of 0.45. The reservoir has a thickness of 34 feet, a good average porosity value of 0.22, and a poor permeability value of 10.4 mD. This characterized the reservoir as being very porous with low permeability, which is characteristic of shaly sand.
Corrosion Inhibition Using Hibiscus Rosa-Sinensis Extract for Mild Steel in an Acidic Medium
Authors: Amabuo Collins , Wachikwu-Elechi Virtue Urunwo , Ikiensikimama Sunday Sunday 
Published: August 2024

Abstract
One significant problem constantly associated with the oil and gas production system is corrosion. As water is an integral part of this system, corrosion among the piping is inevitable. Corrosion tends to disintegrate the piping substance, making it fragile and easy to rupture. The disintegrated parts of the piping could block the system, causing a decline in pressure and contaminating the fluid. Essentially, industries use inhibitors to retard corrosion, and generally, these inhibitors are toxic and exhibit carcinogenic properties. However, these vital inhibitors are still being used in small quantities due to probably non-availability or Sufficient, natural-based corrosion inhibitors. Accordingly, the current study describes the potential of using Hibiscus Rosa-Sinensis Extract as a potential natural corrosion inhibitor for mild steel in Hydrochloric Acid (HCl), an acidic medium with a molarity of 12.178M diluted with distilled water. The method of assessment used in this study is the Weight Loss Method. The effectiveness of Hibiscus Rosa-Sinensis Extract was characterized in terms of metal weight loss and inhibitory efficiency compared to the Conventional inhibitor Disodium Hydrogen Phosphate. Results showed the optimum inhibition efficiency (IE) for mild steel using the same volumes and concentrations for the natural and conventional corrosion inhibitors: 0.3, 0.6, 0.9, 1.2, and 1.5g/L. The inhibition efficiency of Hibiscus Rosa-Sinensis was higher than the Disodium hydrogen Phosphate at concentrations of 0.3g/L, 0.6g/L, 0.9g/L, and 1.2g/L, 1.5g/L. At the same time, after the analysis during the 14-day interval. The commercial inhibitor performed the least in all the concentrations. Hibiscus Rosa-Sinensis and Disodium hydrogen Phosphate attained a maximum inhibition efficiency of 93.72% and 39.24%, respectively, during the 14 days. The inhibition efficiency increased with increasing inhibitor concentration and decreased with immersion time. In addition, the inhibition efficiency shows that the Hibiscus Rosa-Sinensis Extract is more effective after 14 days in the different contractions and volumes. The natural inhibitor performed far better than the conventional inhibitor (Disodium hydrogen Phosphate) used to test.
Deep Water Mitigation of Gas Hydrate Formation Using Alium Cepa Skin Extract (ACSE)
Authors: Onyekachi P. N. , Ikiensikimama S. S. , Wachikwu-Elechi Virtue Urunwo , Okon O. E. 
Published: August 2024

Abstract
The formation of Gas Hydrates is a major flow assurance challenge affecting the Oil and Gas Industry. Hydrates are ice-like, non-stoichiometric crystalline compounds formed at high pressures, and low temperatures usually in the presence of water as the ‘host’, and gases as the ‘guest’. When hydrates form, they tend to clog or plug the flowlines thereby, leading to flow restrictions. This study evaluates the performance of Allium Cepa Skin Extract (ACSE) in gas hydrate formation mitigation. Experiments were carried out using a locally fabricated High Pressure Magnetic Stirrer Autoclave equipment to compare the performance of ACSE to a conventional Kinetic Hydrate Inhibitor (PVP), and to ascertain the inhibitory capacity of the ACSE. For this experiment, Hydrate formation was detected by an increase in the temperature of the Reactor Cell and a drastic decrease in Pressure. The different weight percentages used were 0.01 wt%, 0.02 wt%, and 0.03 wt% respectively. Plots of Pressure, Temperature, and Time of the both inhibitors were made and results obtained were analysed. For the various concentrations (0.01-0.03 wt%) of ACSE, 0.02 wt%, and 0.03 wt% showed a higher inhibitory capacity compared to the PVP. For experiments with 0.01 wt% at the end of 120 minutes for PVP and ACSE, the final pressure drops were 12.3 bar, and 11.2 bar respectively. This shows that PVP was a better inhibitor than ACSE at that weight percentage. 0.02 wt% ASCE proved to be the most effective concentration in preventing gas hydrate formation because at this weight percent, the highest inhibitory capacity was obtained showing that increasing the dosage beyond this concentration would be uneconomical. Although for 0.01wt% which is the lowest concentration, PVP (pressure of 12.3 bar at the end of 120 minutes) performed better than ACSE (11.2 bar), the ACSE solves the challenge of environmental unfriendliness, toxicity, non-biodegradability, and availability. ACSE is eco-friendly, biodegradable, and locally available. Hence, it is recommended that it should be developed as an alternative to the toxic, and hydrate inhibitors used in the Oil and Gas Industry. Since the results of the experimental runs indicated that ACSE had a good performance, it therefore, implies that it may effectively inhibit hydrate when used for field trial.
Examination of the Effect of Salinity on the Recovery of Petroleum in the Course of Water Flooding: An Experimental Approach
Authors: Enoh S. N. , Salihu A. , Okafor I. , Oruwari H. , Gimba A. S. B. 
Published: August 2024

Abstract
Petroleum sector is actively and persistently involved in search of novel techniques to optimize petroleum extraction in the course of water flooding. The oil and gas industry is constantly searching for different methods to optimize oil recovery during water flooding. The type of core material or formation being studied and the salinity of the water injected are two crucial variables that can have a substantial effect on oil recovery. Little is known, nevertheless, about how salt affects petroleum or oil recovery during water flooding utilizing clay-containing core samples. This study investigated the impact of salinity on oil recovery carried out using two core samples obtained from shale rocks. The core sample labelled A was from Kogi state and core B was from Rivers State. Initially both core samples were dried in an oven at 88°C to cause natural fractures and connect the pore spaces then saturated with brine of 20g/l salinity and light crude oil of viscosity 3.35cp to simulate reservoir conditions within the core samples. The porosity of the samples was determined by liquid saturating method and the effective permeability was calculated using Darcy’s law. Core flooding tests were conducted by injecting brine and varying the salinity levels at 10g/l to 30g/l to displace 20 ml of light crude oil originally saturated in each core sample. The results and analysis of the tests showed that the core sample B recovered more oil than sample A. The recovery factor efficiency of core A was 24%, 31.5%, 51%, 53%. and the core sample B was 26%, 42%, 50.8%, 52.1%. The oil recoveries at breakthrough increased significantly with increasing salinity. The difference in oil recoveries for both core samples in breakthrough and final recoveries was observed at 30g/l of brine salinity where core B recovered 8.8% higher than core A. At 50g/l brine salinity, the oil recovery efficiency did not change for both core samples while changing the concentration of brine relative to the initial brine used. The findings of this study and the data retrieved shows the improvement of oil recovery factor increases as brine salinity increases which can be attributed to interfacial tension reduction and viscosity alteration.