bluuebunny/crossref_metadata_2025 huggingface dataset:
Optimization of Polymeric Nanofluid Oil Recovery Mechanisms at Reservoir Condition
Authors: Al_Ani M. , Panis N. I. , Manikumar Y. , Sidek M. A. , Jaafar M. Z. , Ridzuan N. , Gbonhinbor J. , Umunnawuike C. , Money B. , Agi A.
Published: August 2024

Nanoparticles have been used to improve the properties of oilfield polymers however, at higher and prolonged temperature, dihydroxylation of the bonds occurs decreasing the affinity of the oilfield polymers towards the surface of the nanoparticles. Hence, polymeric nanoparticles (LPNP) with rigid structures have been sought after to circumvent this problem. Therefore, in this study, LPNP was synthesized from sago palm (Metroxylon sagu) bark and used as a rheological agent to improve the viscosity of displacement fluids. Thereafter, the synthesized LPNP was characterized via transmission electron microscopy, particle size analysis, zeta potential, Fourier transform infrared spectroscopy and thermogravimetric analysis. Then, the rheological flow behaviour of lignin polymeric nanofluid (LPNF) was investigated at low and high shear rates utilizing a 350 RST Brookfield rheometer. Box-Behnken design was used to simulate the effect of salinity, shear rate, concentration, and temperature on the viscosity of LPNF. Statistical analysis of variance was used to analyse various parameters of the model. Finally, any parameter combination that resulted in the maximum viscosity was recorded and optimized using a multi-response surface model. The synthesis method was efficacious in producing LPNP with a size range of 10–23 nm. Besides, LPNF exhibited shear thinning and pseudoplastic behaviours even at high salinity and showed good stability up to a temperature of 170°C. The predicted viscosity with a regression coefficient (R2) of 0.8 indicates that the experimental data were accounted for by the model. The desirability of 0.95, which is close to unity, indicates that statistical analysis and experimental evidence have demonstrated that LPNF has acceptable flow behaviour under reservoir conditions.
Modelling and Simulation of a CO2 System as a Replacement for Propane in the Pre-Cool Loop of a Propane-Mixed Refrigerant Cycle
Authors: Timighe P. S. , Adeniyi A. T. , Omofoyewa M. G. , Giwa A.
Published: August 2024

To fulfil the energy needs of the nations where it is regasified and delivered via pipelines, specialist tankers transport liquefied natural gas (LNG), a reliable and efficient energy source, across the sea. To improve efficiency and environmental acceptability, research is being done on substituting carbon dioxide for propane in the precool loop of the propane-precooled mixed refrigerant cycle. The primary goal of the research is to compare carbon dioxide and propane as refrigerants for the precooling loop of a propane-mixed refrigerant (C3-MR) cycle, which is utilised to liquefy natural gas, utilising Aspen HYSYS to design the plants. The performance of CO2 and propane were examined in this study using various process factors that were discovered through sensitivity analysis. The study determined both refrigerants’ coefficients of performance (COP), which show how well they cool while consuming less energy. In comparison to propane, which had a COP of 3.555, carbon dioxide showed a slightly higher COP of 3.728, indicating that it was more effective at transmitting heat under the given circumstances. The impact of variations in the precooling refrigerant pressure and molar flow rate on the compressor's duty for the carbon dioxide and propane precooling cycles was also examined in this study. Both refrigerants demanded more effort from the compressors as the molar flow rate was raised, but carbon dioxide fluctuated in compressor duty a little more than propane. In a similar vein, both refrigerants showed reduced compressor workload with increasing pressure, with carbon dioxide once more exhibiting somewhat greater compressor duty changes. Based on the data gathered, the study came to the conclusion that carbon dioxide, with its greater coefficient of performance, superior heat transfer efficiency, safety advantages, and less environmental impact, was the best refrigerant for the precooling loop in the C3-MR cycle.
Optimal Development of a Virgin Heavy Oil Reservoir with Multiple Zones, Fluid Contacts and Structural Uncertainties in the Niger Delta
Authors: Ezeaneche Obinna. S. , Odewoye Oluwatosin , Abdullahi Muhammad , Alaigba David , Udeze Chima Cyril , Oyeleke Kehinde. Z. , Bernard Ebere , Ijeoma Festus
Published: August 2024

Traditionally, the development of heavy oil reservoirs is not attractive to marginal field operators, due to challenges such as low Expected Ultimate Recovery, complex well trajectory, early water breakthrough and high operational cost. However, there has been a recent shift from the old ideology of "abandon" to "development", owing to improved technology and depletion of conventional oil resources. This paper is focused on a virgin reservoir B within the Niger Delta that has good reservoir properties, multiple fluid contacts observed from logs and supported by RFT. The reservoir fluid viscosity is 12cp with an initial solution gas of 32 scf/stb. Two different seismic vintages resulted in two slightly different structural relief. The old seismic vintage shows the structural relief increasing towards the Northeast but in the newly interpreted seismic vintage, the structural high increases towards the Northwest. Simulating these two static model realizations would result in different production profiles. An integrated approach utilizing static and dynamic modeling processes was adopted to evaluate the development of reservoir B. Various well trajectory types were considered during reservoir simulation and well planning. A relatively poor performance was observed from the vertical well path due to rapid water breakthrough. The deviated well path indicated a better performance than the vertical. However, the horizontal well path was finally selected as the most optimal to drain the reservoir due to delayed water breakthrough time compared to the vertical and deviated wells. Sequel to the horizontal well selection, the two structural models from different seismic vintages required the optimization of the horizontal well path whose major constraint was the fixed surface location, and this led to the selection of Well path 3 with recovery of 0.97MMstb. In conclusion, heavy oil field development requires detailed integration of subsurface data to help maximize opportunity.
Assessing the Economic Impacts of Renewable Energy in Sub-Saharan Africa: A GDP-Centric Approach
Authors: Oyegbile M. O. , Emeke Chukwu , Eze M. C.
Published: August 2024

Sub-Saharan Africa, endowed with abundant solar, wind, hydro, and biomass resources, historically faced challenges in harnessing renewable energy due to infrastructural and financial limitations. Recently, the region has seen a surge in renewable energy adoption, driven by technological advancements, declining costs, and increased investments.

This research is driven by the need to quantitatively assess how renewable energy investments and advancements affect economic growth in Sub-Saharan Africa. The study acknowledges the region's unique economic and energy landscape, characterized by vast renewable resources, and aims to understand how harnessing these resources impacts Gross Domestic Product (GDP).

This research paper employs an in-depth analysis of economic data, renewable energy production statistics, and investment trends in Sub-Saharan Africa. Econometric models are utilized to establish correlations and causal relationships between renewable energy development and GDP growth. This approach includes examining the direct impact of renewable energy projects on local economies and the indirect effects through factors like job creation, energy security, and industrial productivity.

Key findings reveal that renewable energy has a positive and significant impact on the economic growth of Sub-Saharan African countries. Investments in renewable energy infrastructure not only provide immediate employment opportunities but also stimulate long-term economic activity by providing reliable and affordable energy. This energy accessibility enhances productivity in various sectors, from agriculture to manufacturing, contributing to GDP growth.

The study recommends policies and investments that integrate renewable energy development with economic objectives. This offers crucial insights for policymakers, underlining renewable energy as a key economic strategy, beyond its environmental and social benefits.
The Study of the Integration Between Pectin and Sodium Dodecyl-Sulfate on Oil Recovery
Authors: Musa M. S. M. , Adam N. H. B. , Gbonhinbor J. R. , Ridzuan N. , Mahat S. Q. A. , Yakasai F. , Ngouangna E. N. , Oseh J. O. , Agi A.
Published: August 2024

Surfactant flooding is a recognized technique within the realm of chemical enhanced oil recovery (CEOR), to enhance oil recovery in cases of continual depletion in conventional oil reserves. This method has a track record of effectively increasing oil recovery rates. The process involves multiple factors, including the reduction of interfacial tension (IFT), alterations in wettability, the creation of foam, and emulsification. Despite its success, a primary concern associated with surfactant flooding is the emergence of increased fingering effects, resulting in conformance issues like excessive water production. The primary objective of this research is to examine the interaction between pectin and sodium dodecyl sulfate (SDS) in the context of oil recovery, assessing the collaborative potential of pectin in conjunction with SDS to amplify oil production, and evaluating the impact of sodium chloride (NaCl) salinity on the behaviour of pectin and SDS in the context of oil recovery. To address water production concerns, this study employs polymer to augment water viscosity. The interaction between pectin and SDS will be scrutinized by observing three distinct sand packs, each containing surfactant, polymer, and a surfactant-polymer combination, respectively. The findings indicated significant improvements in oil recovery using different enhanced oil recovery (EOR) techniques. Freshwater flooding resulted in a 15% increase in oil recovery compared to saltwater flooding. Polymer flooding with a concentration of 0.6 wt% demonstrated the highest efficacy of 77.85% improvement in oil recovery compared to waterflooding. Surfactant flooding, while slightly less effective than polymer flooding, but still showed a remarkable 48.94% increase in oil recovery after waterflooding. However, surfactant flooding's effectiveness could be constrained by factors like reservoir characteristics and fluid properties. Despite this, the study revealed that combining surfactant and polymer flooding with the inclusion of pectin led to substantial gains, boosting oil recovery by 30% - 80% compared to using single polymer or surfactant flooding techniques.
Techno-Economic Analysis of Using Palm Oil Fuel Ash and Quartz for Plugging and Abandonment of Hydrocarbon Well
Authors: Margaret Monday Mary , Stephanie Nwosi-Anele Adaobi , Wopara Fidelis
Published: August 2024

There are large number of wells that need to be permanently plugged and Abandoned (P&A). As P&A operations do not provide any return on investment, developing cost-effective operations methods is very important. Therefore, it is essential to use cost-effective plug-and-abandonment technology without compromising the operation's scope. In this work, Quartz and Palm oil fuel ash (POFA) was used to reduce the cost associated with plugging and abandonment of hydrocarbon wells by reducing the settling time and improving the well integrity by minimizing the shrinkage associated with conventional cement. These materials were selected based on their properties, Quartz a thermodynamically stable material, enables the formulated solid to withstand temperature and not shrink with time despite the temperature and the force applied. The sieve size used for the Quartz was 300 microns and the total gram of 571.6g of the Quartz was added to the cement mixture. POFA possesses a pozzolanic property and a sieve size of 150 microns and 285.88 grams was used for the mixture with the mix ratio of M7 (1:4:8) and M25 (1:1: 2) A total gram of 143g of class G cement was added to the mixture, the water-cement ratio of 0.4 for the mixture of M7 and the water-cement ratio of 0.4 was use for M25. The rheological property and mechanical properties of the formulated slurry were analyzed and compared to that of Class G cement slurry. The Addition of the material (Quartz and POFA) to the class G cement increases the compressive strength from 85 psi to 182 psi and the setting time of 2:20min to reach 50 Bearden consistency. Economic Analysis using cost estimation method was done and the result shows that the cost associated with the usage of the formulated slurry was lower than the usage of class G cement for plugging and abandonment.
Remedial Well Impairment Treatment in Water Disposal Wells: A Field Experience
Authors: Akosa S. P. , Emordi J. C. , Nwachukwu N. E. , Deele H. L. , Awasum C. W. , Agara M. I.
Published: August 2024

Organic and Inorganic Scales, bacteria activity, and waxy agglomerations occurring from Injecting poorly treated produced water into old or depleted perforations can be treated by maintaining the right treatment fluid mix, applied in the right sequence that will allow for easy injection and reduction of high back pressures to surface.

This paper discusses the treatment of two wells with perforation blockage and Wellbore impairments from the injection of produced water which led to high surface injection pressures, prevention of perforation penetration, and fluid migration which ultimately led to shutting down a section of the production facility for months.

The procedure involved using a Coiled tubing workstring for pre-injection testing of the affected wells to develop pressure baselines, mixing and squeezing a stimulation treatment system into the perforations, and then allowing it to cure, while monitoring the pressure drop-off trend. After curing, a post-injection test was conducted to determine the new well parameters for subsequent injections.

The fluid system was designed to treat impairments resulting from organic and inorganic chemical reactions which has caused damage to the perforations and near the wellbore. The selected Well data such as the production profile, and the reservoir information including bottomhole pressure, bottomhole temperature profiles, and perforation intervals were analyzed as various other Well parameters were not known for the candidate wells needed to build a fluid system that could handle the requirements of an unknown causative agent.

Laboratory testing was carried out by simulating the reservoir conditions with the proposed fluid recipe against the actual produced water injected into the wells.

Post-injection analysis of the Wellhead pressure and surface choke indicated that the deployed fluid system caused a reduction in the Wellhead pressure which will allow the continued produced water injection as desired.
Energy Security and Sustainable Development of Nigeria's Oil and Gas Sector
Authors: Oruwari Humphrey Otombosoba , Obunwa Queen , Ahuchogu Joe , Ayuba Salihu
Published: August 2024

Energy security is a critical component of a nation's sustainable development, and for an oil and gas-rich country like Nigeria, it is particularly pivotal. This study explores the multifaceted dimensions of energy security in the context of Nigeria, delving into the challenges, opportunities, and policy considerations that shape the sustainable development of its oil and gas sector. Nigeria is one of the largest oil and gas producing country in West Africa Sub region. The country has been striving to attain national energy security. The methodological framework of the study involves the use of literature review, policy documents and case. The study finding reveals that for a country like Nigeria which is a mono based economy?. Without energy mix, it is very challenging to achieve energy security despite being endowed with fossil fuels. However, Nigeria has the potential to increase its energy security in future by diversifying its energy resources, decarbonizing the oil and gas industry by utilizing its enormous gas resources and integrating with other African countries especially in the energy market. The study also recommends keying into renewable energy especially in this era of energy transition and adopting energy efficiency principle.
Progressive Evaluation and Acquisition Strategies for Improving Success in Re-Entering Abandoned Oil and Gas Well in a Niger Delta Marginal Field
Authors: Ifediora A. , Adesokan I. , Olusola B. , Shittu A. , Osadipe B.
Published: August 2024

With the awarding of marginal fields from the 2020 bid round, indigenous companies and new players in the Nigerian Upstream oil and gas sectors grapple with the legacy of abandoned wells. Reliability of existing data is a common challenge hence, operators had to plan various re-entry strategies to mitigate the unknown risks and improve well delivery, this entails the process of evaluation, acquisition, and re-evaluation of data. The inherited data that come with these wells may have been obtained using obsolete technology or obtained using analogue methods whose results had to be digitized and re-interpreted thereby increasing the possibility of human error. This challenge underscores the necessity of having an effective data acquisition program for optimal reservoir recovery. This study presents strategies for evaluating and obtaining valuable data from abandoned wells in the Niger Delta Basin. It reviews the operations in the AA-01 well in the AA Field as a case study. To address the issues around data reliability and acquisition, a robust data gathering initiative was proposed after initial evaluation – from obtaining well trajectory surveys to integrating advanced logging techniques such as corrosion logs, cement bond logs, pulse-neutron logs, and gamma-ray logs. While preferring innovative data-gathering programs, historical data are also compared and combined with the new data to justify the data acquisition program and give a more nuanced understanding of the geological history of the well. This paper aims to highlight the difficulties encountered by indigenous companies regarding data reliability and solutions while discussing the strategies for a robust data-gathering initiative and its benefits.
Efficient Seismic Survey Design for Enhanced Reservoir Management: A cost Effective Approach
Authors: Chejieh Chibuzor , Yuan Kate , Oni Adeboye , Babatunde Ayodeji , Suleiman Isah
Published: August 2024

Etebi, a deepwater field, has available ullage, necessitating the implementation of surveillance seismic technology on a nearby prospect to maintain optimal tank levels. To achieve this, an Ocean Bottom Node (OBN) seismic survey is planned to establish a 3D baseline for future 4D seismic surveys, enabling effective reservoir management throughout the field's lifecycle. This paper focuses on the application of ray-based and wave-based methods to optimize the survey design and area of interest (AOI), resulting in significant cost reduction and a survey that will ultimately improve reservoir management. By utilizing successful rays that adequately illuminate the subsurface target, the node polygon was constrained, leading to the development of the master node polygon. Additionally, a wave-based technique was used in collaboration with asset geologists, integrating the geological model of the subsurface to further enhance the master node polygon and derive other survey parameters. Diagnostic tools were employed to select the best scenario for the survey parameters and AOI. The study identified the best technical scenario, providing optimal illumination coverage with a cost reduction of approximately 20%. This study has positively impacted the planned OBN survey by reducing cost, optimizing scheduling, and ensuring high-quality data acquisition for enhanced reservoir management.
Polyethylene-Co-Vinyl Acetate (EVA) and Nanoparticle Effect on Wax Deposition: A Molecular Dynamics (MD) Simulation Approach
Authors: Ridzuan N. , Gbonhinbor J. R. , Agi A.
Published: August 2024

Wax buildup is a worldwide concern in oil pipelines, spanning from subsea to processing facilities, leading to decreased oil production rates. An effective way to prevent the formation of solid wax mandates the use of chemical wax inhibitors. Molecular dynamics (MD) simulations were employed to investigate how poly(ethylene-co-vinyl acetate) (EVA) and sodium cloisite (Na+) nanoparticles (NPs) collaborate to inhibit wax formation. The simulations involved examining the behavior of EVA molecules, both with and without the incorporation of NPs, in conjunction with wax molecules. This investigation aimed to elucidate the intermolecular interactions, which influence wax formation and deformation, through radial distribution function (rdf) analysis. The outcomes revealed a substantial shift in the interaction between H59•••H60 in the EVA/NP and wax system, progressing from 2.75 Å in the pure wax system to 3.25 Å. This shift signifies the significant impact of wax inhibitors and nanoparticles in the tertiary system on wax-wax interactions. Consequently, the findings from the cold finger test corroborate that the EVA/NP blend results in the least wax deposition, which is further supported by the simulation results. In conclusion, the incorporation of nanoparticles with wax inhibitors emerges as an efficacious approach for mitigating wax deposition challenges within the oil and gas industry.
Obvious and Salient Incentives and Opportunities for Deepening Midstream and Downstream Operations in Nigeria
Authors: Basaka Hussaini Aminu , Ringim Aminu Uba
Published: August 2024

The comparative advantage of abundant hydrocarbon resources enjoyed by Nigeria for economic development and as mainstay of government revenue has gradually eroded as the incremental capital output ratio (ICOR) continues to increase as the cost of extracting, transporting, and processing of petroleum liquids and natural gas to refined products for storage, domestic supply to local market and export has dwarfed revenues from operations. Incentives, exemptions from certain taxes, provisions for unbundling of business opportunities and activities from expansive implementation approach of the Petroleum Industry Act (PIA) 2021 has provided the required pivot for catalyzing growth. The onset of global mandates for curtailing growth of the fossil industry, changing dynamics of the fuels, petrochemicals, and commodities market, and efficiency gains from smart operating models must and are being harnessed to drive growth, and position Nigeria to embrace the midstream and downstream sector as the fulcrum for economic development. The outcome of these promptings in conjunction with the NMDPRA's regulatory support will engender transparency and accountability, create new markets for petroleum, realize cash flows from new business portfolios, sustain government revenues, and open doors for new investments.
Cluster Gathering of Associated and Non-Associated Natural Gas: The KGG Case Study
Authors: Fagbami D. , Ekpeti E. , Bamidele A. , Odeh A. , Odogbo A. , Jimmy D.
Published: August 2024

The resource rich Niger Delta region of Nigeria, where oil and gas exploration and production activities are commonplace, gas flaring has characterized much of the landscape of the region, with the searchlight now firmly focused on these flares and necessitating urgent measures to help address the resulting environmental scourge. Modular gas processing facilities have long been an efficient means of utilizing flared gas in standalone flare sites with a high degree of success recorded over time. Having such modular plants in multiple locations would require that the output products from these plants be transported by pipelines and/or conveyed via trucks (or vessels in the case of swamp and offshore operations) to the market or consumption centers. Piping from each gas plant all the way to the market will introduce a complex web of piping crisscrossing multiple communities, with a potential for exposure to vandalism and other hazards associated with pipeline infrastructure in the region. Nigeria has roughly 181 trillion cubic feet (TCF) of proven gas reserves plus much more in undiscovered gas resources. However, despite having the largest gas reserves in Africa, only about 25% of those reserves are being produced or are under active development today. The foregoing challenges would require that a safer and more effective strategy would be to lay pipelines from processing facilities located within a Petroleum Mining Lease, acreage or producer cluster to a centralized gas gathering station where each gas delivery line will be metered into a manifold which connects the gas gathering station to the national gas network via a single injection line making gas from the cluster accessible to offtakers from anywhere on the national gas network system. This paper presents a practical case study of one such system, the Kwale Gas Gathering (KGG) facility at Umusam, in Delta State of Nigeria, which highlights the benefits of cluster gathering of natural gas resources from the OML 56 producer cluster.
Polymer Flooding using Nanomaterials: Advances/Recent Trends in Polymetric Nanomaterials
Authors: Kelechi F. M. , Authony E. O.
Published: August 2024

Implementing polymer flooding offshore involves various considerations. Managing large polymer volumes cost-effectively is a practical challenge, requiring maintained rheological properties during transit from surface facilities into the reservoir. Simulations are essential to predict polymer flow in the reservoir, identifying significant mechanisms at the pore and core scales for field behavior. This paper focuses on polymer flooding, a widely used chemical enhanced-oil-recovery technique, providing an update on technology status with an emphasis on field applications rather than theoretical or laboratory research. Topics covered include mechanisms of polymer flooding, types of polymers used, polymer-solution stability, technical screening criteria, laboratory and simulation work, performance-monitoring techniques, summaries of pilots and large-scale applications, experiences and insights from field projects, polymer flooding in heavy-oil reservoirs, polymer viscoelastic properties, issues associated with polymer flooding, and potential solutions. The presented data and analysis offer readers updated information on polymer flooding, serving as a guide for relevant research. Survey data also provides operators with reference information for project design and optimization, contributing to the understanding and improvement of polymer flooding practices.
Maximizing Well Construction Strategy for Combined Appraisal and Development in Stacked Reservoirs –A Case Study
Authors: Orji Mirian Kosi , Olatunbosun Ademola , Kumapayi Olamide , Abe Gbenga , Inwere Ihuoma , Bassey Nina , Akinpelu Jumoke , Benson Esigie
Published: August 2024

This paper highlights the value-driven development strategies deployed in designing and constructing a multi-reservoir appraisal and development well. The reference field is a shallow water offshore brown field in Nigeria and has been producing since 1997 with significant remaining hydrocarbon resource in place. These strategies were based on a cross-functional holistic view of the development objectives, which revolved around appraisal data acquisition needs, expected volumes, cost, execution complexity and optimal well sequencing. The approach influenced the planning of a multipurpose appraisal/producer well to optimize the re-development of several reservoirs in the field.

A broad appraisal and development scope such as this, came with attendant complexities for which well design and execution strategy had to be optimized. This paper further describes the strategies deployed to manage the identified well construction risks:

Well trajectory intersecting multiple hydrocarbon bearing reservoirs with depleted pressures Drilling across multiple faults with risk of lost circulationDeep well collision risksExtended openhole exposure due to logging requirements in the production section andComplex completion assembly installation–2-string completions at >15,000ft with multiple jewelries (downhole gauges, gas lift mandrels etc.)

This strategy ultimately improved drill-well campaign economics by over 60%, saved the cost of drilling two heel pilots, and acquired critical data that helped optimize other wells on the rig schedule. Subsurface data gathered from this well, integrated with production data helped articulate different possible subsurface scenarios that impacted completions designs and optimal reservoir management plan. Data from this appraisal/producer well also aided the optimization of reservoir production and development strategies towards achieving incremental uplift from 3 streamed producer wells and additional potential for future development.
Examination of Geotechnical Properties of Structures of a Swamp Marginal Field Development in the Niger Delta
Authors: Osadipe B. , Adesokan I. , Olusola B. , Shittu A. , Ifediora A.
Published: August 2024

A geotechnical survey was carried out in a swamp location in Niger Delta, Nigeria. The primary aim of the geotechnical investigation is to gather crucial data on the physical characterisation of soil consistency in the area. The investigation was carried out by conducting site characterisation, laboratory testing, and data analysis. As a result, the geotechnical survey was conducted on land, swamp, and water (river). Two (2) boreholes labeled BH1 and BH2 were dug on land, each of which is 40 meters deep. The sample rate for BH1 and BH2 is 0.75 meters. Based on the sample rate of 0.75 meters, soil samples collected for each borehole were 53 samples. A total of 106 soil samples were collected for BH1 and BH2. Six (6) boreholes were dug over water, each at a depth of 20 meters with a sample rate of 1 meter given the total soil samples collected to be 120 samples. The boreholes were dug to determine the contents of the soil in each location. BH1 revealed a clay formation from the ground surface to a depth of 11.0 meters, and fine sand was encountered with a band of clay between 11 meters and 20.25 meters. Clay was discovered from 20.25 meters to the final 40.0 meters of the investigation. Similarly, on BH2, a formation of clay was observed from the ground surface to a depth of 34.50 meters, and fine sand was encountered at 34.50 meters and 40.0 meters depth. The moisture content of the clay layers ranges from 31-163 %, indicating that the clay has a low to high moisture content, as is typical of marine clays, with bulk unit weights ranging from 12.52-19.44 kN/m3. The liquid limit values range from 88-140 %, the plastic limit from 27-42 %, and the plasticity indices from 61%- 98 %. The sand's SPT N-values range from 6 to 14, indicating that it is loose to medium-dense in compaction. Furthermore, the riverbed boreholes revealed entirely clay formation with no trace of sand within the depth explored. This information is vital for designing the surface structures to be erected in this location.
Assessing the Attractiveness and Progressiveness of the Fiscal Framework in the 2021 Nigeria Petroleum Industry Act Under a Zero - Carbon Emission Strategy
Authors: Nwosi-Anele Adaobi Stephenie , Iledare Omowunmi
Published: August 2024

The global trend for cleaner energy and zero emission has made the need for frameworks that support reduced to zero carbon emission necessary. This is in a bid to make zero-carbon emission a success. Laws and frameworks that encourage the strategy for zero emission should be introduced. The Nigerian Petroleum Industry has been on a journey of continuous review of its petroleum fiscal frameworks that existed as the petroleum industry bill between 2009-2020, until the final passage of the bill into an Act in 2021. The zero emission strategy would be a success in Nigeria if the fiscal frameworks favor the exploitation and production of natural gas resources rather than crude oil; this is because natural gas produces cleaner emissions than crude oil. This means that fiscal frameworks that encourage investments in the natural gas upstream, midstream and downstream sectors should be formulated and enacted. This paper reviews the Petroleum Industry Act 2021, its attractiveness to investors in the natural gas sector and it's progressiveness towards the needed change in the oil and gas industry towards zero-carbon emissions. It looks at the provisions of the Act and how it encourages investors in the natural gas sector. It is recommended that fiscal frameworks for oil and gas sector should be progressive to accommodate modifications in the sector and should encourage zero-carbon emission in this new era.
Simultaneous Real-Time Top-Of-Cement and Memory Cement Evaluation Delivery in Deepwater Operations, Nigeria
Authors: Jenakumo Timipere , Umeh Nnaemeka , Ugoh Oluwatobi , Onuigbo LSD , Oyedipe Peter Oluwaseyi
Published: August 2024

Cement bond logs are traditionally acquired via wireline after the well has been drilled to its total depth. Waiting for wireline-based cement bond logs usually takes time and can cause delays in obtaining timely completion approvals from regulatory bodies. Turnaround times for providing cement bond logs (CBL) have been drastically reduced with the introduction of quantitative cement evaluation based on logging while drilling (LWD) memory data.

Further optimization of the delivery time of these cement bond logs has now been achieved with the introduction of simultaneous real-time top-of-cement (TOC) and quantitative cement evaluation services. Real-time TOC ensures the availability of CBL across the casing of the previous hole section, even before drilling the target reservoir section. Top-of-cement behind casing is identified in real-time, facilitating an immediate approach of the regulatory agency for completion approval. The consistency between real-time TOC and quantitative cement evaluation services based on LWD memory data provides a more robust decision on well integrity based on cement bond integrity.

Real-time top-of-cement and Cement Evaluation services acquired in recorded mode were simultaneously delivered in two deep water wells to validate their application – a first in Deepwater Operations in Nigeria. This paper presents the outcome of the work and outlines the workflow for providing the required CBL with the fast turnaround needed to obtain timely completion approval.
Oil Production Prediction Using Time Series Forecasting and Machine Learning Techniques
Authors: Omotosho Temitope James
Published: August 2024

Prediction of oil production is critical for the oil and gas industry, as it helps production engineers plan and execute strategic decisions. In the past, various empirical correlations and mathematical models have been utilized for this purpose. However, with the advent of data-driven techniques, machine learning algorithms such as Random Forest (RF), Artificial Neural Network (ANN), Long Short-Term Memory neural network (LSTM), Recurrent Neural Network (RNN), DeepAR, and others have been adopted for predicting oil production. This paper presents a comparative analysis of time series forecasting and machine learning techniques for predicting oil production, using the ARIMA, Prophet, Random Forest, CatBoost, and XGBoost Algorithms. Time series forecasting involves building models based on historical data and using them to make predictions for the future, while machine learning algorithms use data to train models that can accurately predict future outcomes. The study aims to develop a prediction model for oil production using daily production data obtained from the Volve production field in Norway. Results from this study demonstrate that while time series forecasting had a larger error margin and a negative coefficient of determination (R2 Score), while machine learning techniques improved the accuracy of the prediction, with the stacked regressor algorithm having an R2 score of 97.5%. Feature selection was done for the prediction, and features such as bottom-hole pressure, bottom-hole temperature, annulus pressure, choke size, and tubing downhole pressure contributed to the more accurate prediction of oil production.

In conclusion, the satisfactory results of the comparative analysis demonstrate the effectiveness of machine learning algorithms in predicting oil production. This study can serve as a reference for production engineers looking to develop more accurate oil production prediction models using machine learning techniques.
Designing a Fully Customizable Low Pressure, High-Speed Rotating Reamer Shoe System for Tubular Deployment
Authors: Nkwocha C. O.
Published: August 2024

Conventional reamer shoes are either mechanical or hydraulically actuated. Mechanical systems include products that require the entire casing, liner, or completion string to be rotated from the surface by applying rotary action on the string. This operation may result in extremely high torque requirements upon the entire tubular running system. Other mechanical systems include auto-correcting, weight-actuated, and j-slot key-based mechanisms. Mechanical systems tend to have little or no torque output unless where string rotation is introduced.

Hydraulically actuated reamer shoe systems include a turbine, Moineau pump, or an internal jetting drive system. The internal jetting and turbine drive systems create high rotary speeds with low to medium torque outputs. The inverse Moineau pump system, commonly known as positive displacement motors has a different mechanism similar to having two helical gears with one gear having one additional thread, referred to as lobes. Turbine and positive displacement motors are both referred to as mud/down-hole motors in a broader sense. Positive displacement motors are known for lower rotary speeds compared to turbine motors and, therefore, better suited for a wide variety of drilling applications.

This paper examines the major design considerations for changes to a high hydraulically actuated reamers shoes system and provides case histories and the value to operations where these tools have been deployed.
Lower Carbon Optimal Development of Heavy Oil: Swamp Niger Delta Case Study
Authors: Fagbowore Olufisayo , Onyeji Johnbosco , Oragwu Aluba , Chukwuka Clement
Published: August 2024

The share of light oil in the global oil reserves continues to decline given that oil and gas producing companies have historically placed more focus on developing the light oil fields. This is because light oils can typically be produced at high rates and low costs. This decline has led to an increasing effort to develop and produce high viscosity oil which accounts for about 15% of the global oil reserves.

However, to develop and produce heavy oil at commercial production rates, there is almost always a need to reduce the viscosity of the crude as well as introduce additional energy into the reservoir. The most common methodology implemented to produce such viscous crude involves the injection of superheated steam into the reservoir. This helps to reduce the viscosity of the oil, increase the reservoir pressure, increase the displacement of the oil in the porous rock media as well as achieve partial distillation of the oil. Other methodologies revolve around injection of polymers and surfactants to improve the sweep of oil in the reservoir. These methodologies require significant facility capital to develop the process of generating steam or handling the polymer/surfactant. As such, all these methodologies lead to a significant increase in the carbon footprint of operations as well as increased operational costs when compared to light oil production. There is therefore a need to assess other development strategies that will not require significant cost for development and lead to high carbon intensities.

This paper presents practical case studies of development of heavy oil reservoirs in the swamp Niger Delta region without using the traditional super-heated steam or polymer/surfactant injection which lead to increase in carbon footprint. The case studies highlight some of the challenges associated with producing heavy oil (inflow challenges, inadequate vertical lift, early water breakthrough due to adverse mobility ratios, amongst others) and show examples of production optimization methodologies that led to wells achieving peak rates that are comparable to those observed in conventional light oil wells in similar depositional environment and with similar well completion types.
Application of Artificial Neural Network to Predict Downhole Conditions of Oil Wells Using Wellhead Data
Authors: Edet Ita Okon , Atubokiki Ajienka Joseph , Livinus Aniefiok , Chinedu Ikenna Ndubuka
Published: August 2024

An accurate prediction of downhole conditions using wellhead data is highly vital in petroleum production engineering applications. It is very useful in the management of the life cycle of a well. Although there are techniques in literature to predict downhole conditions using wellhead data; however, most of these techniques are empirical correlations derived from few datasets. The study presents a new robust and self-computing approach that was developed using Levenberg-Marquardt algorithm in MATLAB software. This model predicts the downhole conditions such as pressure drawdown (ΔP) and productivity index (PI) using wellhead data. The model was trained and validated using 3200 production data points from eleven (11) oil wells in the Niger Delta. The model predicted both the ΔP and PI with a training accuracy coefficient of determination (R^2 ) of 0.980 and the root mean square error (RMSE) of 13.560. This prediction closeness resulted in R^2 and RMSE values of 0.964 and 2.552 for ΔP and 0.964 and 2.552 for PI. The performance analysis of the newly developed ANN model against some of the input variables for ∆P were analyzed. It was observed that choke size less than 40 has a wide spread percentage error bandwidth, though majority of the predictions falls below the ±40 percentage error. For the effect of GOR on the performance of the newly developed model, the percentage error bandwidth is quite high, but majority of the predicted values are in the +20 and -40 range. The water cut data affect the performance of the model when it is less than 20. However, for water cut values greater than 20, the percentage error predictions are within the ±20 range. The results suggest that the ANN model presents a better choice for the prediction of downhole conditions with minimum error and acceptable accuracy.
Injection Order: A Determinant for the Performance of Alkaline-Surfactant and Polymer Flooding Scheme
Authors: Kinate Bright Bariakpoa , Elikee Uchenna Daniel , Igwe Ikechi
Published: August 2024

The combined approach of alkali, surfactant, and polymer (ASP) injection is considered the most promising and enhances oil recovery by reducing residual oil saturation and improving sweep efficiency. However, the performance of ASP flooding is highly sensitive to various factors. Among these factors, the injection order of the chemical components significantly impacts the effectiveness of the process. To optimize ASP flooding, it is essential to understand the chemical interactions and mechanisms involved in each injection order. Hence, this work will evaluate the impact of injection order on the performance of ASP flooding. Computer Modelling Group (CMG) pre-processor, Builder was used for the creation of ASP input file (dataset) and STARS module for the validation of the dataset and for prediction. Six (6) order, ASP, APS, PSA, PAS, SPA, SAP were created and each evaluated for 12years, comprising of 4 years interval for each chemical components. The cumulative oil produced, oil production rate and field oil recovery factor were determined for each order. The APS order gave the highest cumulative oil production with the SPA order having the least. Similarly, APS order gave the highest field oil recover factor with the least from SPA order. The result shows that alkali must be injected first to generate soap for interfacial tension (IFT) reduction, followed by the polymer injection to change the mobility ratio and lastly, surfactant to produce an optimal surfactant concentration to further reduce the IFT between oil and formation water to an ultra-low level.
Corrosion Inhibition of Mild Steel Using Terminalia Catappa Leaves Extract (TCLE) in 1M HCl Solution
Authors: Olaonipekun P. B. , Ikiensikimama S. S. , Wachikwu-Elechi Virtue Urunwo
Published: August 2024

The oil and gas industry plays a vital role in driving global economies by meeting the energy demands of nations. However, the industry faces significant challenges in maintaining the integrity and longevity of its infrastructure due to the corrosive environments in which it operates. Conventional corrosion inhibitors typically rely on synthetic chemicals, such as disodium hydrogen phosphate (DSHP), which have raised environmental concerns due to their potential toxicity and ecological impact. As industries increasingly adopt sustainable and eco-friendly practices, there arises a critical need to explore alternative and environmentally friendly corrosion inhibition approaches that offer comparable or superior effectiveness. This research investigates the viability of Terminalia catappa leaf extract (TCLE) as an eco-friendly corrosion inhibitor for mild steel (measuring 3cm x 4cm) in 1M HCl solution. Utilizing the weight loss method over a 14-day period, the study compares the performance of TCLE to DSHP. The green extract was obtained using the maceration technique; Terminalia catappa leaves were blended, soaked in ethanol for 60 hours, filtered, and then concentrated. It was found that TCLE demonstrates an improvement in inhibition efficiency with increasing concentrations but diminishes with prolonged immersion time. A maximal inhibition efficiency of 89.24%, 94.12%, 94.12%, 93.64%, and 96.20% was observed for TCLE at the concentrations of 0.3g/L, 0.6g/L, 0.9g/L, 1.2g/L, and 1.5g/L respectively, markedly contrasting with DSHP’s peak efficiency of 10.57%, 13.25%, 20.25%, 31.65%, and 39.24% at 0.3g/L, 0.6g/L, 0.9g/L, 1.2g/L, and 1.5g/L concentrations respectively. Over time, TCLE’s efficiency demonstrated impressive durability; even after two weeks, it inhibited with a notable 55.68%, 71.19%, 80.33%, 82.55%, and 83.38% efficiency at the concentrations of 0.3g/L, 0.6g/L, 0.9g/L, 1.2g/L, and 1.5g/L respectively. In sharp contrast, DSHP dwindled to 4.16%, 4.43%, 4.43%, 4.71%, and 8.59% efficiency at the concentrations of 0.3g/L, 0.6g/L, 0.9g/L, 1.2g/L, and 1.5g/L respectively by the end of the experiment. In conclusion, this evidence positions Terminalia catappa leaf extract (TCLE) as a promising and environmentally conducive alternative for the corrosion inhibition of mild steel. It demonstrates superior efficiency compared to disodium hydrogen phosphate (DSHP), a conventional synthetic inhibitor. It is recommended that TCLE should be harnessed and upscale for application in the industry‒wide corrosion inhibition strategies.