bluuebunny/crossref_metadata_2025_split huggingface dataset:
Modelling and Simulation of Liquid-Loaded Gas Flow
Authors: Okafor Chinonso , GIWA Abdulwahab , Gidado Abdulkabir 
Published: August 2022

Abstract
Liquid loading of gas wells gives rise to problems in the wells and diminishes their complete recuperation. A few authors proposed various models to predict the beginning of liquid loading in gas wells, yet the outcomes from the models regularly show disparities. Turner et al.'s basic model was developed based on the understanding that the liquid droplet is a sphere and stays spherical all through the whole wellbore. Thereafter, Li's model was formulated with the understanding that the fluid drops are flat in shape and stays the same all through. Furthermore, Maduabuchi's model was proposed in line with the previous models by presenting a distortion coefficient "C" to cater for the disfigurement of the liquid droplet along the wellbore and, thus, have the option to effectively foresee the basic rate when the droplet fluctuates from the circular shape to the level shape. In this work, another model has been developed and simulated with the aid of MATLAB program to anticipate liquid loading in gas wells. In the new model of this work, Maduabuchi et al.'s model was utilized while relating the drift flux equations and their parameters (distribution coefficient, C0, and the drift velocity, uD) in a modified form. The drift flux parameters were incorporated to cater for the impacts of mixing of the liquid and gas droplets. The newly developed Model predicted the critical velocity with a fitting accuracy of coefficient of determination (R2) of 0.9547 compared to other models. Maduabuchi et al.'s model has coefficient of determination (R2) of 0.8987, Li et al.'s Model has R2 value of 0.8987 and Turner et al.'s model has coefficient of determination (R2) of 0.8939. Consequently, the new evolved model was discovered to be a quick and robust tool for estimating exactly the beginning of liquid loading of producing gas wells.
Achieving Safety at Sea – Discussing the Safety Programs Implemented by the Nigerian Upstream Petroleum Regulatory Commission
Authors: Nwankwo Okechukwu , Edem Michael , Muku Jennifer , Ike Chidi , Ogionwo Ebipador 
Published: August 2022

Abstract
Over 70% of Nigeria's oil and gas reserves are in swamp and offshore environments with over 40,000 workers registered to work there. Following the signing of the Petroleum Industry Bill into law, the Nigerian Upstream Petroleum Regulatory Commission (NUPRC) as the successor agency of the Department of Petroleum Resources (DPR) is the upstream industry regulator mandated to drive several safety programs to protect people, environment, and assets through enforcement of laws and regulations. The aim of this paper is to discuss the various safety programs adopted by Commission to reduce accidents in swamp and offshore areas, in which bulk of the oil and gas operations occur. A detailed review of the programs showed that in addition to protection of people, environment and asset, safety programs drive cost savings in the industry, improves collaboration among operators, creates jobs and other economic opportunities in Nigeria. This paper will discuss in detail, the background, methodology, successes, challenges, and opportunities of some flagship safety programs of the Commission. The programs to be discussed are - Administration of Offshore Safety Permit; Implementation of Safety Case; Annual Facility Inspection and Oil Spill Contingency Plan; Risk Based Inspection; Safety and Emergency Training Center and Medical Center Accreditation and Search Rescue and Surveillance Program. This paper only gives insight into the management of safety in the Nigerian oil and gas industry and does not attempt to review the performance or effectiveness of these safety programs vis-à-vis accident statistics in the industry. The various safety programs can be adopted by regulators around the world most especially in countries with a nascent oil and gas industry.
Idle Wells Reactivation- The Kenyon International Story
Authors: Ekpenyong Victor , Joseph Amieibibama 
Published: August 2022

Abstract
With increasing concern for life and environmental safety, and an encouraging upward trajectory in the oil price, there is the need for the government and operators to actively invest in the reactivation of idle wells by putting the right enablers in place. Reactivation of idle wells has been proven to be more economically attractive to add to existing potentials than new exploratory activities. This paper showcased a case study of the reactivation of AKOS-004LS well, and outlined strategies developed by Kenyon International in collaboration with the Nigerian Upstream Regulatory Commission to effectively manage idle wells in Nigeria for economic and social benefits. AKOS-004LS is a dual completed well with a combined potential of about 5,300bopd before it was shut-in due to a previous recorded fire incident that compromised the integrity of the well structure. As part of the reactivation process, the well structural integrity was restored, sustained casing pressure issue investigated and resolved, and a zonal change was carried out in the long string to produce new oil and additional barrels to the operator. The estimated cost for a conventional rig-based workover operation to restore the structural integrity of the well is about $12m but the workover operation was eventually executed at a cost far below $5m with the deployment of the proprietary rigless Integrated Wells Management Plan by Kenyon International. The combined potential of the well was also restored to its original potential of about 5,300 bopd, producing optimally from both strings. This proprietary Integrated Wells Management Plan by Kenyon International is a game changer as it has proven to to be technically efficient, cost effective and has the potential to reduce the number of emerging idle wells, thus, contributed to incremental potential and overall reduction in health and safety concerns.
Machine Learning Prediction Versus Decline Curve Prediction: A Niger Delta Case Study
Authors: Jayeola Ifeoluwa , Olusola Bukola , Orodu Kale 
Published: August 2022

Abstract
Several analytical techniques have been identified to obtain reliable estimates of production. Out of these numerous methods, decline curves are the most extensively used technique for the production forecast of Niger Delta Reservoirs. However, a major setback in applying the decline curve is its inability to adapt predictions to different past operational scenarios and uncertainties. With the emergence of big data and increasing computational power, machine learning techniques are increasingly being used to solve problems like this in the oil and gas industry. The objective of this paper is to present the application of a machine learning-based framework to predict the future performance of producing wells in some reservoirs in Niger Delta. In this paper, a machine learning model (Neural Networks model) was used to detect the non-linear relationship between the inputs in the production data and predict the future production rate of wells. The model is trained using available data from a Niger Delta Reservoir. Further data, excluded from the training data set, was used to assess the ability of the neural network to rapidly learn the basic shape of the time series data and model the non-linear relationship of the data for prediction. The different case studies are compared to forecasts from conventional decline curves to demonstrate the advantage of applying machine learning techniques to production forecasting. The proposed technique indicates high accurate prediction and learning performance for crude oil forecast of producing wells, especially for cases with changing operating conditions. The study also reflects that the performance of the model is largely influenced by the model-optimization technique. The research work provides empirical evidence that the proposed model can be applied to production forecasting, addressing complexities that other statistical forecast methods cannot implement. The proposed application of computational techniques in forecasting problems has proven to be a robust and reliable method of forecasting the future performance of producing wells. The procedures adopted in this work can also be extended to wells outside of the Niger Delta.
An Integrated Approach To Production Optimization In Ageing Gas Lifted Fields- Ikanto Field Experience
Authors: Obong Benjamin , Adegoke Pius , Osuji-Bells Soba , Ogbonna David , Salisu Hassan , Ekerenduh Onyinyechi , Adomokhai Segun 
Published: August 2022

Abstract
In many ageing fields, there is a constant need to optimize production performance of the wells to ensure that they continue to deliver value. As a field matures, with high water and sand cut production from the wells, water breakthrough from water flooding projects and other artificial pressure maintenance programs, the produced fluid water cut and gas-oil ratio will be changing. For such fields, the optimal use of existing surface facilities is critical to sustaining and increasing well rates leading to a corresponding reduction in production costs.
In the Ikanto field, Gas Lift is the preferred artificial lift method, and has been so for over twenty years. However, with increased water production from the wells, the field separating train is faced with handling produced water in the separator train. Other challenges in the gas lift system including obsolete field metering equipments, meter calibration and maintenance challenges, etc, have impacted optimization opportunities from the gas lifted wells. The resulting consequence is the inability to fully determine optimal lift gas injection rates if the lift gas injection into the well is over or under-injected in line with advised lift gas rates from well performance models. An important input for gas lift optimization is the volumetric flow rate of injection gas. This data can help experienced Production engineers and field technicians determine if the lift gas injection into the well is optimal, thus providing directional guidance on what change(s) should be made to improve the well performance.
In order to ensure that the asset value is enhanced, an integrated approach to maximizing production from the field was deployed ranging from the upgrade and automation of the existing gas lift infrastructure in the field vis-à-vis carrying out gas lift system optimisation, carrying out de-bottlenecking of parts of the production system, and the installation of real time surface monitoring systems.
In this paper, the results of the optimization efforts in the Ikanto field are discussed. The analysis of the results has resulted in an upscale of total daily production from the field by over thirty percent (30%).
Effective Data Acquisition Using Logging While Fishing Technology: A Case Study
Authors: Akiba-Eyo Effiowan Ansatasia , Aduwo Akinyemi Tolulope , Chime Chukwudalu Emmanuel , Oguara Emi Ndidamaka Odite 
Published: August 2022

Abstract
The planning and execution of drilling highly deviated, tortuous wells increases the risk of key seating of the wireline cable or differential sticking of wireline logging tool strings downhole, during formation evaluation/ data acquisition for appraisal wells. The need to manage this cannot be overstated as it presents a high risk of financial exposure resulting from extended fishing operations, potential lost-in-hole charges or failure to acquire essential subsurface data which could run into millions of dollars.
Pressure measurements and fluid sampling, as part of formation evaluation and reservoir characterization, continue to provide critical information for appraisal well objectives. These suites of tools tend to have the highest probability of differential sticking/ cable key seating due to the long periods required to obtain near uncontaminated reservoir fluids during pumping and sampling operations that are suitable for PVT based analysis. This paper highlights operational challenges, troubleshooting, effective cost-management, and overall successful data acquisition including recommendation based on the Case Study of a Logging While Fishing (LWF) operation. This event occurred onshore in the Niger Delta where the cable of the wireline logging tool was trapped in the groove channel (key seating) in the wellbore during the Pressure and Fluid sampling logging operation. Understanding the complexity of such operations will lead to effective management of risks via the utilisation of available technologies and techniques in preventing and/ or mitigating future occurrences of stuck logging equipment.
New Oil Formation Volume Factor Correlation for Nigerian Crude Oils
Authors: Atthi Aneel Jordan , Sulaimon Aliyu Adebayo , Akinsete Oluwatoyin Kunle 
Published: August 2022

Abstract
A comprehensive description of reservoir fluid properties is critical in developing solutions and resolving reservoir engineering issues. The oil formation volume factor, βo, is an indispensable reservoir fluid property in reservoir engineering calculations. In this study, we used a total of 11040 data points from 1840 oil samples to develop new βo correlations for the Nigerian crude oils specifically, and another set of correlations for the other regions herein referred to as the global crude oils. Linear regression (LR), multiple linear regression (MLR), multiple non-linear regression (MNLR), neural network (NN), support vector machine (SVM), and the group method of data handling (GMDH) techniques were used to develop several correlations. Results show that the GMDH method yielded the best correlation while the MNLR is the least accurate. The root means square error (RMSE) for the Nigerian, and Global correlations are 0.0033, and 0.0256 respectively. The two correlations are reliably better in terms of accuracy than the existing correlations. The new correlations would facilitate a more accurate reservoir characterization, and reliable design of surface equipment.
Sustainable Development in the Niger Delta: Interrogating the Role of Multinational Oil Corporations
Authors: Ogwus Chinedu 
Published: August 2022

Abstract
This paper invstigtes the extent Corporate Social Responsibility (CSR) initiatives of oil companies operating in the Niger Delta area of Nigeria contribute to the development of host communities across the region. This empirical study precisely adopts the mixed-methods approach which involves the use of qualitative and quantitative methods for data collection and analysis. Using the purposive sampling technique, a total of 113 participants were recruited for the study, and they included managers, senior and junior cadre employees, community leaders, market women and youth representatives. Findings of the study revealed that through the provision of key infrastructures such as schools, hospitals, and access roads, oil companies contributed significantly to the development of host communities. However, the majority of the study participants (74 per cent) reported that the quality of projects executed by oil companies was usually of low quality and lacking in durability. Also, the majority of the study participants (58 per cent) reported that there is an inadequate collaboration between oil companies and members of the host communities on the choice and location of CSR projects. Therefore, based on the findings of this study, it is recommended that there is a need to ensure international quality standards in the execution of CSR projects within the Niger Delta sphere. This will enhance the public image of oil companies which are usually considered as corrupt, exploitative, and insensitive to the needs of host communities. Also, the study recommends the need for greater collaboration between oil companies and their host communities in determining the choice and location for CSR projects. This will help to ensure that CSR projects of oil companies align with the needs of host communities.
Reconstructing Deposition Environment Using Energy Regime Assessment of Stacked Sequences from Gamma Ray Log and 3D Seismic Data
Authors: Rotimi Oluwatosin , Chukwuka Somto , Oyeyemi Kehinde , Ogunkunle Temitope , Akande Ayodeji , Ihekona Betty , Iyamah Oseremen , Alege Tope 
Published: August 2022

Abstract
Depositional sequence unbundling was done to understand the depositional environment from six wells through the analysis of gamma-ray logs using shale volume, and a 3D post-stack seismic. Identified hydrocarbon reservoir formations were laterally tracked to assess horizon continuity and spatial draping of the units. Horizon surfaces were built post-correlation to examine the bounded zones and reconcile sequences. Gamma-ray log motifs for the deposits indicate the presence of progradational, retrogradational, and aggradational sequence patterns that typifies prevalent energies at the time deposition, characteristic of deltaic environment. On the seismic sections, aggradational reflectors dominate over the other two. Although current well placements do not conform to structural attitude, petrophysical analysis done over the horizons indicate a significant increase in porosity and hydrocarbon saturation basin-ward (South-west), in the direction of the frontier prospect to site more wells.
Selection of Optimal Sand Exclusion Methods for Wells in The Onshore Niger Delta: The Ibigwe Field Case Study
Authors: Chime Chukwudalu Emmanuel , Kalio Ibinabo Greenson 
Published: August 2022

Abstract
Sand production is a pertinent issue in oil and gas well engineering and a major cause of concern for the production engineer. He can plan for it, or he can prepare for it, albeit he would rather have it nipped in the bud right from the well’s completion phase. Sand production is costly, reducing the lifetime and durability of pipelines and production facilities, inadvertently impacting the company’s balance sheet negatively and in some cases reducing the life and productivity of the well itself. This paper critically evaluates sand production in the Niger Delta, using the Ibigwe field operated by Waltersmith Petroman Oil Limited as a case study. It proffers optimal sand exclusion methods for wells in the Niger Delta by analysing various subsurface datasets and historical sand production from offset wells within the field. The subsurface datasets identified as relevant to this study include sonic transit time, depth of burial of zones of interest, particle size analysis, geomechanical data (specifically unconfined compressive stress logs), Rate of Penetration (ROP) and other data logs. Evaluating all relevant data to the subject is imperative as discovered during research; none of the datasets listed above can be analysed in isolation, rather interdependently. The selection of an optimal sand exclusion method consequently affects the deployment of an effective completion mechanism and as such, this endeavour should be carried out conscientiously.
Optimising Process Conditions to Obtain Distillate Properties Within Regional Specifications
Authors: Oyeyele Adebimpe , Junaid Camilla , Idris-Idah Kawu , Olomolaiye Daniel , Robert Eretoru 
Published: August 2022

Abstract
In this work, a case study of a modular crude oil refinery is carried out. Located in Imo State, Nigeria, it is the first refinery to simultaneously produce four (4) petroleum products - Naphtha, Kerosene, Automotive Gas Oil (AGO) (i.e., Diesel) and Heavy Pour Fuel Oil (HPFO), that have constantly met the requirements of the Nigerian Department of Petroleum Resources (DPR). The refinery is situated beside the Ibigwe Marginal Field from which it obtains its crude oil; it represents perhaps the personification of efficiency in maximizing value from petroleum resources. Numerous lessons exist for prospective modular refiners.
The paper aims to identify optimal process conditions and discuss a data-focused strategy utilized in ensuring optimal distillation column parameters required to achieve the production of "on-spec" (that is, meeting the desired regulatory/client quality specifications) distillates. The set points of temperatures and pressures for the distillation and stripping of each product were examined, while assessing the impact of changes in feed stock properties, product specifications or ambient conditions and the adjustments that needed to be made to process conditions. Some examples of the concerned characteristics of the product required to meet specification are API Gravity, Flash point and Pour Point. The reflux temperature, petroleum products draw rate, etc. are few variables to be appropriately manipulated. Strategies were developed and implemented for all stages of the refinery’s development – preliminary ones being the Design stage and Construction stage, with the ongoing one being the operation stage.
Literature alludes to refiners categorizing "meeting specifications" as a potential problem. For example, you have now obtained "on spec" kerosene, what quantity of "on spec" diesel is left? In this paper, the technical journey to meeting DPR requirements is narrated, aiming to transfer knowledge and further develop the nation’s ability to meet its energy needs.
Overpressure in Process Facilities: Case Study of a Modular Refinery
Authors: Olomolaiye Daniel , Idris-Idah Kawu , Junaid Camilla , Robert Eretoru , Oyeyele Adebimpe 
Published: August 2022

Abstract
In this work, using the case of a modular refinery we study the pressure profiles in different sections of the process. This information is used to identify the various systems where overpressure occurs, as well as evaluate the contingencies put in place to control it. Cases where the controls are inadequate and the implications on process continuity are also assessed.
To solve the challenge created by overpressures in a process facility, an evaluation of the root cause and a clear definition of the conditions under which they occur were done. Certain thermodynamic principles, in combination with process conditions, fluid characteristics, and the mechanics of the process, will be applied to highlight areas at risk of overpressures and recommend proactive steps to mitigate them. Modifying process design to account for overpressures could create a headache that "pounds more than a square inch". What controls should be put in place to cater to these pressures, what measurement and monitoring equipment should be used, and does the risk of overpressures justify the economic implication of this additional equipment? And finally, do these measures compromise the performance of the facility? These are the questions that were answered in taming this "Wild beast".
In process design, pressure control is key to achieving operational continuity. Much like a perfect equestrian performance, a process operating within its design conditions can be very fulfilling. There is a great need to plan (design) to ensure your show horse (process fluids) responds appropriately to obstacles (process conditions) it meets along the way. The effect of pressure on flow, temperature, phase behaviour, and volumes makes it an indispensable tool to control process conditions.