bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Comparative Study of Acoustic Emissions from Pencil Lead Breaks on Steel and Aluminum Substrates Using Signal Analysis
Authors: Fatukasi Oluseyi. S. , Abolle-Okoyeagu C. J. , Pancholi K. 
Published: August 2024

Abstract
Pipeline infrastructure is crucial in various industries, such as water management, transportation, oil, and gas. Detecting and monitoring potential failures or leaks in pipelines is paramount to ensure safety, prevent environmental damage, and optimize maintenance strategies. Acoustic emission (AE) is a passive non-destructive testing technique commonly used in pipeline monitoring, it detects faults caused by leaks, cracks, and external impacts in various engineering materials. Calibration is an important aspect of any AE monitoring process, and the Pencil-lead break (PLB) technique is highly effective in characterizing acoustic wave speed and calibrating the AE experimental setup. Producing a PLB AE source involves breaking a 0.3mm diameter pencil lead by pressing it against the surface of a test structure and applying a bending moment. This produces energy in the form of elastic stress waves, propagating through the test structure before being recorded and transformed into electrical signals by a transducer mounted on the test surface. In this paper, a comparative study of the behaviour of steel and aluminum substrates based on their time-frequency energy distribution from the burst impact of pencil lead breaks is conducted. This is accomplished by simulating AE PLBs in a controlled laboratory experiment on solid steel and aluminium cylinders (200mm diameter) surfaces to generate acoustic emission signals captured by the Piezoelectric transducer attached to the test objects. The acquired signals were analyzed using MATLAB software to study the differences in spectral behaviour on the test objects. The results indicate that the AE energy and average frequency are lower in the solid steel cylinder than in the aluminium cylinder due to differences in their relative density and strength. The response model will provide a theoretical foundation for future structural AE monitoring of oil and gas pipelines.
Combating Subsea Pipeline Corrosion Using Papaya Leaves
Authors: Igwe Justus Uzoma , Odutola Toyin Olabisi 
Published: August 2024

Abstract
Over the past two decades, numerous pipeline networks within Nigeria's oil and gas industry have experienced severe failures. This is largely attributed to the corrosive nature of the operating environment and the transportation of corrosive fluids through these oil pipelines. In this research, the Papaya leaf extract (PLE) was prepared and utilized to slow down the corrosion of Subsea Pipelines (SP) in harsh offshore environments. The experiment was conducted using the gravimetric (weight loss) method, using 12 specimens (coupons) comprising three metal coupons in the proportion of four Aluminum, four Mild steel and four Galvanized Steel. The coupons were kept in a workable state to prevent them from any preferential attack. The coupons were rinsed in distilled water, dried, and weighed to obtain the initial weights. Each coupon was immersed into a beaker containing 200 ml of seawater polluted with 1M H2SO4 solution and varying PLE concentrations. Through a five-day exposure period and varying PLE concentrations (8 ml, 12 ml, and 16 ml), the experiment utilizes a control group (0 ml PLE) to gauge inhibitor effectiveness. Quantitative analysis of weight loss (WL) and corrosion rates (CR) provided critical insights into the inhibitory potential of PLE for subsea pipeline corrosion prevention. Notably, the efficiency of the 16 ml inhibitor demonstrated superior performance, showcasing overall efficiencies of 19.44%, 79.82%, and 86.03% for AL, MS, and GS samples, respectively. Also, the MS had the least weight loss at 13.4% proving to be a better material choice for subsea pipelines. This research contributes essential quantitative data, emphasizing the impact of PLE concentration on corrosion resistance and positioning PLE as a promising eco-friendly inhibitor for subsea pipeline protection.
Effect of Oil-Based Drilling Fluid Contamination on Gas Condensates Fluid Properties. Case Study of a Deepwater Reservoir in Niger Delta, Nigeria
Authors: Attoni S. D. , Nwonodi C. , Nwaokorie C. 
Published: August 2024

Abstract
Fluid characterization is a key input into reservoir and field development studies and effective wells and reservoir management. Thus, the importance of acquiring representative reservoir fluid samples cannot be over emphasized. Fluid samples acquired from the reservoir may be contaminated by drilling fluid. However, with advancements in reservoir fluid analysis and characterization, it is possible to numerically clean contaminated reservoir fluid samples.
This paper presents a case study of the effects of Oil-based drilling Mud (OBM) contamination on gas condensates fluid properties from a Deepwater turbidite reservoir in Nigeria. Four contaminated samples acquired from this reservoir were studied.
The results show that drilling fluid contamination has a marked effect on key gas condensate fluid properties such as the Condensate-Gas-Ratio (CGR). The higher the contaminant the higher the CGR of the contaminated and resultant cleaned fluid. Numerical cleaning of OBM contaminated gas condensates does not guarantee obtaining a fluid model that is representative of insitu uncontaminated reservoir fluid. A linear relationship was observed between the cleaned fluid CGR and Saturation Pressure (Psat) with respect to the contamination level. Extrapolation of this relationship to 0% wt. contamination yields a CGR and Psat that were likely to be indicative of insitu uncontaminated fluid CGR and Psat. This formed the basis for a low case PVT parameter estimate, thus enabling the definition of suitable fluid parameter uncertainty ranges. The paper also highlights the importance of acquiring multiple fluid samples and benchmarking fluid description against possible analogues within the same and/or similar geological setting to enable the development of possible insights that may support and improve the analysis.
Non-Conventional Approach in Installation of Gravel Packing: A Case Study in Niger Delta
Authors: Emeke Chukwu , Agho Sandra Ekpe , Okoye Cyprian 
Published: August 2024

Abstract
Sand production in oil and gas wells can lead to reduced productivity, equipment damage, and increased operational costs. Effective sand control measures are essential to mitigate these issues and maintain optimal well performance. Gravel packing is a widely adopted technique for sand control, typically involving sealing off upper perforations to prevent sand ingress. However, this paper explores an unconventional gravel packing approach that allows upper perforations to remain open while effectively controlling sand production in the lower zone of a dual-perforated well. In a case study conducted in Field X of the onshore Niger Delta, an aging well, X-03, presented challenges due to sand production and well integrity concerns. Instead of the standard practice of sealing upper perforations with cement before gravel packing the lower zone, an innovative gravel packing method was implemented, involving a detailed wellbore cleanout, perforation cleanup, and gravel packing with upper perforations remaining open. The paper analyzes the unconventional technique's performance, risks, and impact on production, comparing it to conventional methods. In order to achieve this, the sand production in the upper zone needs to be low, meticulous hole cleaning and effective communication between the completion team, the rig crew and the gravel pumping team. This paper provides valuable insights into unconventional sand control techniques, offering a reference for future operations. It highlights the adaptability of sand control methods to specific well conditions, demonstrating that unconventional approaches can yield successful outcomes while reducing operational risks.
Re-Analysis of Petrophysical Properties of Some Selected Fields in the Niger Delta
Authors: Malanta A. T. , Okologume W. C. 
Published: August 2024

Abstract
Petrophysical properties play a crucial role in evaluating the potential of hydrocarbon reservoirs and optimizing hydrocarbon strategies. These properties mainly include lithology, porosity, permeability, and water saturation. To analyze these properties, rock properties are measured and evaluated using well log measurements. This helps to identify the limitations and pitfalls of well-log analysis techniques and find ways to improve the accuracy and reliability of reservoir characterization. The study analyzed three fields in the Niger Delta region using well-logged data. The logs were used to determine porosity and water saturation directly, while permeability was determined using permeability correlations after a thorough study of the fields. The Timurs, Wyllie & Biggs, formation permeability, and Wyllie and Rose 1 correlations were used to get different values. Among the three correlations, only the formation permeability correlation provides reasonable values. The study shows differences in porosity, permeability, and water saturation within the seven reservoirs. The porosity values range from 0.1599 to 0.35, the permeability ranges from 36.813 mD to 14425, and the water saturation ranges from 0.024 to 1. The reservoirs have excellent porosity and permeability, with good hydrocarbon accumulation. The differences in porosity and permeability indicate the heterogeneity of the reservoirs in the Otakipo field. The formation permeability correlation is recommended for reliable results, and local correlations and investigations might yield more precise findings. The study emphasizes the importance of considering the distinctive geological features of each region when assessing correlations between global petrophysical variables.
Estimation of Distance Between Interfering Wells Using Python Programming Language
Authors: Etekuwoma K. E. , Adewole E. S. 
Published: August 2024

Abstract
The knowledge of the distance between two interfering wells is very important and forms part of the objectives of interference well test analysis. Ascertaining if wells are in communication with each other, especially if the wells do not have the same ownership is key to every operator, for flow boundary definition, arbitration, and neighbouring well location, either as relief or recovery well.
The procedure utilizes pressure distribution of a vertical well in a reservoir exhibiting infinite-acting behavior. The total pressure drop in the observation well is aggregated using the superposition of multiple wells with multiple rates histories.
The general equation solved eventually comprises of either single or multiple exponential integrals as major variables. A single linear equation is formed if only two wells are involved. Multiple linear equations are formed if at least two wells are involved. An observation well may also be active.
If only two wells are involved, the solution to the equation is provided using the secant method of finding roots to estimate the distance. Where well pairs are selected for flow and observation, multiple linear equations are obtained. In all cases, only well distance apart is involved.
Python as a programming language is deployed to automatically search for the distance between two wells or an average distance between wells in a multiple array of wells completed in the same or neighboring reservoirs in communication. Major inputs into the program are observed pressure drops and time, wellbore, reservoir, and fluid properties. The program outputs well distance, reservoir, fluid, well parameters and time for every run. The roles of the wells were interchanged as observation and active wells in turn, just to strengthen confidence on results obtained. Two wells (Well 1 and Well 2) were used for demonstration successfully. Distances between the wells as computed by the program compared closely to those manually computed.
Viable Options for Managing Thermally Induced Wellhead Movement
Authors: Bakenne Sulaiman , Oboh Stephen , Vivian Ihejirika , Ugwa Iheanyi , Afamefuna Okenna 
Published: August 2024

Abstract
Surface wellhead upward movements may be observed if high temperature fluid stream flows through a well tubing conduit resulting into thermal expansion in the unsupported tubular sections. This is often associated with flowing of high temperature gas injection, high rate high temperature producer or steam injection wells. Initial well design must anticipate these thermal loads and safely manage this movement to prevent damage to well or topside components through optimum pipe specifications, adequate cementing job design and topside flowline movement tolerance to allow predefined magnitude of wellhead movement. Over the well lifecycle, fatigue and degradation could result in increase in unsupported well sections resulting in an amplified thermal load impact. Therefore, periodic surveillance is critical to ensuring thermal loads remain within the safe operating envelope.
This paper focuses on non-rig based options to managing wellhead movement to ensure safe well operations on a case study gas injector well A. Options evaluated include lock restraint design/installation, displacement of production annulus to insulating packer fluid and lastly defining a safe movement window.
For this case study well A, multistring wellhead movement modelling was done using WELLCATTM. Result of analysis showed that a lock restraint option resulted in significant pipe compression and buckling potentially outside the design envelope. Thermal insulating fluids reduced thermal loads though marginal in this case study due to limited annular clearance. Last option considered was constraining injection temperature to ensure a safe wellhead movement margin that keeps pipe loads within design envelope.
Implementing a systematic workflow to manage wellhead movement will enable operators adopt a balanced and fit-for-purpose strategy to minimize safety risk and maximize well service life.
Human-Centric Rig Move Planning: Bridging the Gap with Human Factors Engineering for Enhanced Safety in Drilling Operations
Authors: Ajimoko Olutayo 
Published: August 2024

Abstract
This paper explores the integration of human factors engineering principles into rig move planning to enhance safety in the oil and gas industry. It discusses the significance of considering human factors such as fatigue, stress, communication, and decision-making in rig move operations. By adopting a human-centric approach, the paper aims to mitigate the risks of human errors and accidents during drilling activities. Through the application of human factors engineering methodologies, including task analysis, workload assessment, and ergonomic design, the paper proposes strategies to optimize rig move planning processes and improve operational safety. The study emphasizes the importance of collaboration between drilling personnel, engineers, and safety professionals to develop effective rig move plans that prioritize human factors considerations for enhanced safety outcomes.
Formation Gas Quantification in the Z-Field Niger Delta Using Multidetector Pulsed Neutron Well Logging Technology
Authors: Akagbosu P. , Kim Y. , Adesokan I. 
Published: August 2024

Abstract
The quest for optimal gas detection and quantification in Niger Delta regions for sustainable energy development necessitates advanced technologies. This paper explores a multidetector pulsed neutron well logging technology with improved formation gas sensitivity for precisely characterizing reservoir fluids and estimating gas saturation in a freshwater environment. This innovative method is applicable to tight porosity and low water salinity formations, which are historically challenging conditions for accurate saturation analysis with conventional pulsed neutron logging applications.
This technology encompasses (1) a pulsed neutron generator that creates high-energy neutrons that interact with formation nuclei and create induced gamma rays and (2) three gamma-ray detectors and an electronics system that records induced gamma rays based on the gamma-ray energy level and arrival time. In addition, forward modeling of tool responses is a critical component. Monte Carlo N-Particle (MCNP) modeling simulates the three-detector pulsed neutron tool’s gas-sensitive log responses. The predicted MCNP models are incorporated into the saturation analysis workflow to identify and quantify the formation gas saturation considering reservoir fluid properties, lithologies, well completions, and cement densities.
A case study demonstrated the use of multidetector pulsed neutron well logging technology for quantitative formation gas evaluations of cased-off reservoirs in the Z-field Niger Delta. This contributes to the use of gas resources for sustainable energy development in Africa.
Management of Scale Deposition in Deepwater Subsea Systems: An Offshore West African Case Study
Authors: Uvieghara E. A. , Chiejina L. C. , Obunabor R. R. 
Published: August 2024

Abstract
Deposition of mineral scales in the wellbores and on production flowlines can cause loss of millions of dollars due to production deferment and equipment damages. This financial impact becomes greater in an offshore environment particularly for subsea assets.
In a deepwater field located in West Africa, production comes from 11 sandstone reservoirs of varying reservoir properties. To improve ultimate recovery of the field, treated seawater is injected into the reservoirs via subsea injector wells to provide sweep to their paired subsea producer wells. Initial study of the field highlighted the need for scale inhibition at the topside due to the self-scaling nature of formation water and incompatibility of the formation and sea water at low pressures and surface temperatures. Thus, scale inhibition had always been done continuously on the topside to minimise the risk of scale deposition.
During a routine pigging exercise of the subsea flowlines, scale was recovered unexpectedly, with large volumes that led to a stuck pig and higher than planned production deferment. Analysis of the recovered samples was carried out with the objective to understand the mechanism causing the subsea scale deposition, identify the exact location of the deposition and develop an effective subsea scale management strategy.
The methodology for carrying out this investigation involved a detailed lab analysis on the scale recovered subsea, followed by a compositional analysis of the produced water of all wells on the impacted flowlines. The result of the compositional analysis was then used in a Scale Prediction Software to determine the scaling culprits.
This paper presents the multidisciplinary approach used in analysing the problem of subsea scale deposition in an offshore asset using actual scale samples recovered during the pigging exercise. An insight to the deposition mechanism will be discussed as well as what led to the deposition. The paper also discusses the various experiments done to identify the suitable subsea scale inhibition deployed and the results obtained from the subsea scale inhibition. Furthermore, this paper also highlights recommendation to mitigate future subsea scale deposition.
Comparative Study for the Successful Implementation of Compressed Natural Gas (CNG) Solution in Developed and Developing Countries
Authors: Ugolo J. U. , Iwegbu M. C. , Onwuchei A. 
Published: August 2024

Abstract
Nigeria in the recent past has faced dual-fuel (petrol and diesel) shortages. The non-functional or sub-functional refineries have made the availability of these products even more scarce and expensive for the average Nigerian. The key source for the petroleum commodities identified has been importation, which has further depleted the much-desired forex required by the nation. Inversely, Nigeria has abundant Natural Gas Reserves estimated at 209 trillion cubic feet (NUPRC, 2023). A large chunk of her natural gas reserves is produced and exported leaving the domestic market with a meager portion for domestic utilisation for her rising population with a relatively low impact on national development.
The use of Compressed Natural Gas (CNG) as a transport fuel therefore provides a two-fold opportunity to alleviate petroleum import dependency and reduce the economic pressure, especially for foreign exchange and subsidy expenditure. There is the current clamour for the implementation of Compressed Natural Gas usage in the country, but this if not well directed, could become a monumental failure and further exacerbate the economic situation of the country. There is a need for a well-guided and intentional implementation of the usage of CNG to ensure that its populace benefits from this natural and abundant resource.
The study employed a qualitative inquiry approach, using a comparative study of secondary data from academic literature, published reports, online sources, and grey literature. The study aimed to identify the predominant themes from other climes by adapting compressed natural gas development initiatives from nine different countries with relevance to Nigeria. The writer posits that well- specified strategic objective, adequate legal framework and backing, learning and adaptation from previous implementations elsewhere in the world, appropriate and well-defined assignment of responsibilities to key players, adequate financial incentives, holistic and appropriate natural gas pricing, and natural gas vehicle (NGV) infrastructure development would be required to successfully implement compressed natural gas in Nigeria
The study therefore concluded that a key factor for NGV market development in Nigeria is a well-coordinated implementation approach with greater government involvement required in setting strategic goals, developing the legal and regulatory frameworks, private sector partnership for infrastructural development, as well as assigning responsibilities to specific agencies. The short-term low-cost policy is encouraged and offering limited support for refueling and retrofitting facilities