bluuebunny/crossref_metadata_2025 huggingface dataset:
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

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

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

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

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

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

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

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

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
Road to Decarbonization: The Role of Liquefied Natural Gas (LNG) as a Transitioning Energy Source for Transportation in Nigeria
Authors: Alozie Chinenye , Chukwudi Kaitochukwu , Nwadike Desmond , Ayodele Emmanuel
Published: August 2024

The removal of fuel subsidies in the petroleum sector in Nigeria has led to a drastic increase in petroleum products prices by 200 percent. It has caused a rapid increase in transportation costs and ultimately contributed to a high cost of living and unbearable inflation. Nigeria, having one of the largest reserves of natural gas in Africa. It can leverage liquefied natural gas (LNG) and, by extension, liquefied compressed natural gas (L-CNG). These fuels hold immense potential as a cleaner, cost-effective, and environmentally friendly energy alternatives. The transport sector can benefit from this fuel source. It can provide significant relief to the local economy that is heavily reliant on traditional fossil fuels like petrol and diesel. A massive adoption of LNG/L-CNG as a mobility fuel will significantly reduce the emission of greenhouse gases from vehicles in Nigeria. It will also encourage positive climate action and limit its contribution to global warming. The adoption of LNG/L-CNG as a transitioning fuel is beneficial to a wide range of industries in Nigeria. However, it is projected to present several challenges. These challenges include distribution and availability of fuel, switching technology and cost, technical support, sustainability, and acceptance rate. This paper describes the role liquefied natural gas (LNG) and, by extension, liquefied compressed gas (L-CNG) as a transitioning fuel for automobiles in Nigeria compared to fossil fuels. The research shows that CNG emits almost 40% less CO2 than oil and about 80% less than coal during combustion. This paper considers suitable conversion kits i.e. the aftermarket CNG fuel kit to facilitate switching. An economic feasibility analysis was used to compare the running costs of CNG and petrol for privately owned vehicles that cover an average distance of 100km daily for 30 days a month. The findings revealed a monthly savings of N214,350. The payback period for using CNG as an alternative fuel was approximately 3 months, given a conversion cost of N600,000. The recommendations include adequate infrastructural development, government incentives, good policy structure etc. was presented to help Nigeria utilize her LNG potential. In conclusion the use of liquefied natural gas (LNG) and liquefied compressed natural gas (L-CNG) as an automotive fuel plays a vital role. It can help revolutionize Nigeria's transportation industry by offering environmental benefits, economic opportunities, enhanced energy security, technological advancements, and policy support.
Energy Economics of Midstream and Downstream Petroleum Sectors in Nigeria: A Review of Potential Optimizations
Authors: Aniebo I. N. , Mogbo O.
Published: August 2024

The energy economics of the midstream and downstream petroleum sectors in Nigeria are important due to the country's reliance on crude oil and gas production and its role in the global energy landscape.

This paper presents a comprehensive review of the potential optimizations in energy economics within Nigeria's midstream and downstream petroleum sectors. It explores the current state of these sectors, highlighting the inefficiencies and opportunities, and goes further to discuss the economic implications of these inefficiencies, emphasizing the need for optimization.

Potential optimization strategies are then proposed, focusing on technological advancements, policy reforms, and infrastructural improvements. The paper underscores the role of renewable energy integration and digital transformation in enhancing energy efficiency.

The economic benefits of these optimizations such as cost savings, increased profitability, and improved competitiveness are analyzed. The paper concludes by emphasizing the urgency of implementing these optimizations, considering Nigeria's energy demands and the global shift towards sustainable energy practices.

In conclusion, this review paper provides valuable insights for policymakers, industry stakeholders, and researchers interested in energy economics and sustainability in Nigeria's midstream and downstream energy sectors. It serves as a guide for future research and policy formulation to optimize Nigeria's petroleum sectors for economic growth and sustainability.
Green Hydrogen: A Comparative SWOT Analysis of the Green Hydrogen Market in Sub-Saharan and Northern Africa
Authors: Nwakaudu Nneoma Faith , Igwe Justus Uzoma , Ohanyere Ifeanyi
Published: August 2024

Africa, characterized by its abundant solar and wind energy resources has been identified as a potential leading player for green hydrogen (Hydrogen produced using renewable energy), IEA 2022. In November 2022, the Africa Green Hydrogen Alliance, (AGHA) described Green hydrogen as a clean and sustainable alternative to conventionally produced hydrogen, and is expected to play a key role in achieving net-zero and decarbonizing hard-to-abate sectors in the coming decade. An analysis by McKinsey Global Energy Perspective projects a significant growth in the global demand for hydrogen by 2050 - almost sevenfold to 607Mt in an achieved commitments scenario. Looking ahead, it is clear that green hydrogen could transform the continent’s energy landscape, from a net importer of fossil fuels to a major exporter of green energy.

This paper conducts a comparative SWOT analysis of the green hydrogen market in African regions. It analyzes the internal strengths and weaknesses, as well as external opportunities and threats shaping the green hydrogen market in Northern and Sub-Saharan Africa, citing existing case studies and statistical data. The research findings reveal a significant growth momentum following an exponential rise in project announcements for electrolyzer capacity, and a 60% hydrogen production cost reduction, positioning green hydrogen as a leading, cost-effective, low-carbon, and clean energy solution by the end of the decade. This paper concludes with policy recommendations that serve as a guide for creating effective frameworks and strategic decision-making on the adoption of green hydrogen in Africa.
Integrating Permeability Data from DST Interpretation to Characterize Deepwater Gas Turbidite Reservoir in Niger Delta: Lessons Learnt
Authors: Nwonodi Chike , Nwaokorie Chukwuemeka , Gritciuk Stanislav , Attoni Success , Awa Chukwunweike , Ibukun Samson , Oladiran Olanrewaju
Published: August 2024

Data acquisition in deep water environments is critical in de-risking subsurface uncertainties and data must be of high quality before development plans can be put in place and sanctioned, given the expensive associated field development costs. In exploration and appraisal drilling campaigns for deepwater environments, one of such data acquisition is via the Drill Stem Test (DST), essential to understand the turbidite reservoirs; characterize and reconstruct the depositional environment. One key challenge in the deepwater environment is the connectivity and thinly bedded nature of the reservoirs with obvious vertical heterogeneity and varying layer flow properties.

DST is commonly used to acquire formation pressures, reservoir fluid samples and determine the productivity of the formation. In this study, the DST was run in a deep offshore gas reservoir with a net thickness of 49ft over a perforated interval; 13,215 ft MD to 13,294 ft MD. The objective was to quantify average formation dynamic flow capacity (permeability-thickness product), well productivity, prove sufficient gas resources for further development of the structure and obtain information about the lateral extent and architecture of the sand bodies. A series of multi-rate drawdowns and build-ups were extracted from the DST and used for the analysis. The Kappa Ecrin well test interpretation software was used to interpret the DST and from the test, formation properties such as skin and permeability as well as insights about the Infinite-acting radial flow (IARF) and boundaries effects were evaluated.

This paper demonstrates the use of DST interpreted results with core data to estimate the range of permeability uncertainty for varying stratigraphy or facies in a deepwater gas reservoir in the Niger delta. Although, the reservoir boundaries could not be fully detected due to limited pressure Build-up (PBU) periods, various model scenarios were evaluated to estimate the range of permeability values using the limited transient phase. Thus, outcome of the interpretation was used to quantify the range of permeability from both the DST and the core plug permeability measurements within the reservoir ranging from 250mD to 1900mD. Finally, this paper also used permeability data from wireline log and DSTs to complement geological and seismic data interpretations and establish the range of uncertainties in permeability.
Evaluating the effect of unmodified and modified starch (EDTA-DSD) as fluid-loss control additives in locally-sourced bentonite water-based drilling mud
Authors: Dike Humphrey N. , Kolade Grace O. , Adewumi Chizoma N. , Adewumi Olakunle C. Daramola N. , Olaniyan Damilola D.
Published: August 2024

Drilling oil and gas wells for hydrocarbon exploration involve high fluid loss costs. Minimizing the fluid loss is crucial to the drilling process to preserve the mud's qualities and to avoid formation impairment. Research has shown positive use of carboxymethylcellulose (CMC) and imported bentonite in the formulation of water-based mud to minimize fluid loss, however, increases the operating cost while the local bentonite has shown increased filtration losses. The aim of this study is to evaluate the rheological and filtration properties of water-based muds formulated using unmodified and modified starch with ethylenediaminetetraacetic acid (EDTA-DSD), a locally sourced material as a fluid loss additive and hyperdrill as a viscosifier at low-pressure low temperature (LPLT) and high-pressure high temperature (HPHT) conditions, and their performances were compared with CMC as reference fluid loss additives. Thermogravimetric Analysis (TGA), Scanning Electron Microscope (SEM) were harnessed to study the properties of these starches while the starch modification was achieved through acetylation and carboxymethylation. Full-set measurements of laboratory tests were conducted to evaluate the influence of adding 0.5-2g of CMC, unmodified and modified starch to the mud samples respectively, and measurements were taken using mud balance, viscometer, low-pressure and low-temperature filter press, chemical titration, and other standard drilling fluid laboratory equipment as recommended by API. Result showed that Plastic viscosity, PV for unmodified starches ranged from 14-17cP, Yield point, YP ranged from 25-31lb. /100ft2,filtrate volume ranges from 18-31ml at LPLT and 30-43ml at HPHT while PV for modified starches ranged from 14-15cp, YP ranged from 27-31lb. /100ft2, filtrate volume ranges from 17-31ml at 100psi and 19-43ml at 500psi of pressure. Experimental results indicate that the filtrate volume and cake thickness compare favorably with CMC, has the capacity to withstand HPHT conditions and are within the American Petroleum Institute specification for water-based mud. Thus, demonstrate its suitability for current and future exploration and exploitation of oil and gas resources.
Unconventional Approach to Re-Entry of Abandoned Well: Case Study of Saro-1 well
Authors: Kpone-Tonwe Hannah , Etim Ntietemi
Published: August 2024

There-entry of an abandoned well with a reclaimed top surface involves complex procedures and innovative technologies. A traditional approach is to prepare the location in such a way that the surface is at the depth where the casing was cut off before burial. Another conventional option involves welding the casing back to the surface. However, this approach could cause leaks in the future, hence there is need to utilize casing patch. This paper describes the experience gained in successfully re-entering and reviving a 43-year-old abandoned exploratory well, Saro-1. The wellhead consisted of a 20" conductor pipe capped with a cement plug. The challenges were in finding the buried well and safely bringing it to surface level. The re-entry operation involved constructing a cellar pit, installing casing patch, extending the severed casing to the surface, and performing wellhead installation. The paper further highlights the work programme designed and implemented to successfully re-enter and revive the well. Challenges encountered, best practices adopted and lessons learned from the operation are also described. The project's success underscores the importance of local knowledge, stakeholder collaboration, continuous risk analysis, and the use of bespoke solutions tailored to specific formation characteristics. Documented operations and constant technical engagement ensured clear communication and understanding among all personnel. This case study not only revived the Saro-1 well as a dual string multiple oil producer but also provided valuable insights and best practices for future re-entry projects, contributing to the industry's efforts to enhance production and address environmental concerns associated with abandoned wells.
Biodioesel Production from Desert Dates (Balanite Aegyptiaca) Seeds
Authors: Salihu A. , Wasiu A. T. , Gimba A. S. B. , Oruwari H.
Published: August 2024

Petroleum is presently the most dominant source of global supply of energy; the consumption of it is on the increase due to the advance in technology, innovation and human population growth. In order to overcome this challenge, the production of biodiesel using heterogeneous- or homogenous-based catalyst has been considered in view of ease of catalyst separation from the mixture and low energy consumption. This study aimed to investigate the production of biodiesel using calcium oxide obtained from river snail shells through calcinations method at 800 oC for 4 hours in a muffle furnace and used as catalyst for the production of biodiesel from desert date seed oil. The chemical composition of the calcined river snail shell was determined by XRF (X-ray fluorescence) techniques. Desert date seed oil was transesterified into biodiesel using electromagnetic stirrer device. Methanol was introduced with CaO into the reaction vessel containing the desert date seed oil. The Central Composite Design method was achieved at varied temperature of 50-60 oC and the catalyst concentration between 0.5-2.0 wt% at constant reaction time of 1 hour 30 minutes after which the mixture was allowed to settle and the methyl ester (biodiesel) was separated from the mixture. The characterization of desert date seed oil methyl ester showed that the biodiesel had a flash point 65 oC, pour point of -4 oC, cloud point of 2 oC, acid value of 3.92 mgKOH/g and density of 0.87 g/cm3 and these values are all within the range as specified by ASTM (American Society for Testing and Materials) and EN (European Norm) standards for biodiesel. The FTIR (Fourier-transform infrared spectroscopy) analyses also reveal that desert date seed oil contains much oil content that makes it suitable raw materials for biodiesel production. The maximum response yield of biodiesel was 90% at the temperature of 60 oC and catalyst concentration of 0.5 wt%. This work further shows that derived catalyst obtained from river snail shell can be used as catalyst to produce biodiesel through transesterification process.
Evaluating the Performance of Bio-Polymers for High Temperature Proppant Suspension
Authors: John A. O. , Akosa S. P. , Onyima K. K. , Feyi-Waboso O. N. , Asante S. Y.
Published: August 2024

Gravel Pack fluids are usually formulated to match the Well conditions and achieve the job objectives. Rheology, proppant suspension and transportation to the desired interval in the Well, predictable polymer degradation rate, and minimal formation damage are key fluid properties that determine the choice of polymer for the success of gravel pack operation. Various commercial polymers are currently available or in use to blend polymeric fluids. Hydroxyethyl cellulose (HEC) and Xanthan gums are one of the most popular gelling agents and are often readily available. Fluids formulated with Biopolymers such as Xanthan gums have shown some superior performance over Cellulose-based fluids such as HEC. In this study, Xanthan gum-based fluid and another biopolymer termed "Bio-2" were subjected to stringent conditions, based on a job design request. The Well temperature is between 190 °F to 210 °F and it was requested that the polymeric fluid should be able to suspend at least 10% of the proppant for 30 minutes after conditioning at the downhole conditions. The test result showed that 70 lb/1000gal (ppt) and 80 ppt of the Xanthan fluid showed good rheological properties with shear-thinning behavior and good gel degradation properties with sodium persulfate (SP) breaker, but 70ppt Xanthan fluid failed the proppant suspension test, while 80ppt Xanthan fluid passed the test at 190 and 200°F but failed at 210°F. Bio-2 also showed good rheological properties with a lower concentration of polymer of 40 ppt and excellent proppant suspension of 0% at 30 minutes at all the tested temperatures. Moreover, an organic acid was observed to be the most effective gel breaker for Bio-2 at low concentrations. Therefore, Bio-2 may be deployed in Wells with more challenging requirements, such as in highly deviated or long horizontal Wells, shunt packings, and other stringent conditions that require excellent proppant suspension and thermal stability.
Impact of Production Data in Decision Making, Past, Present and Future: Examples and Case Studies
Authors: Kumapayi O. Y. , Ishola A. P. , Inwere I.
Published: August 2024

The growing increase in the cost of business operations alongside current cash constraint has driven most decision makers to critically explore data acquisition from a value-driven standpoint. This study focused on leveraging insights from previous data acquisition learnings in Asset X-Y-Z and use the learnings as a yardstick to drive future business decisions and investment opportunities in the asset.

The strategy employed in this study were to identify high value and low-cost impactful data that could influence asset profitability, leverage results from historical data acquisition impact to drive learnings for future business decisions and investment opportunities, and ultimately provide bespoke solutions to surpass prevailing data acquisition challenges and unlock future volume potentials in Asset X-Y-Z. A structured cross functional approach was adopted to mine data across several multifunctional teams, quality checked, and associated value analyzed.

The result showed that Asset X-Y-Z had gained significant value from historical multiple data-driven decisions that has helped influenced better facilities optimization, successful reservoir management and project execution. Study results show a higher future potential to be recovered in the long term from future data dependent opportunities.
Formation Evaluation of Low Resistivity Low Contrast Hydrocarbon Clean Sands Using Well Logs and Saturation Height Function
Authors: Udeze Chima Cyril , Ndubueze Maduabuchi , Ringim Mohammed , Ezeaneche Obinna S.
Published: August 2024

Identification and estimation of hydrocarbon volumes in Low Resistivity Low Contrast (LRLC) pay zones has always been a challenging exercise. It is more challenging to evaluate and estimate hydrocarbon volumes in a clean sand formation with low GR API above established hydrocarbon-water contact or free water level. Low resistivity low contrast pay sands are hydrocarbon bearing reservoirs that have low resistivity due to several factors such as mineralogy, shale content, microporosity, salinity, anisotropy, bed thickness to mention a few.

These hydrocarbon bearing formations are easily assumed to be wet by mere looking at the typical log responses of GR-RES-DEN-NEU combination, resulting in wrong volume estimate, loss of value by not completing hydrocarbon bearing intervals based on log interpretation and difficulty in history matching production against estimated volumes when the intervals are completed and producing.

It is also important to note that the presence of these low resistivity low contrast pay clean sands at the reservoir crest with no known shale barrier or baffles demarcating the low contrast pay sands from the hydrocarbon sands which gives the impression of water on top of hydrocarbons. These LRLC pay sands have been observed across several reservoirs in this field of study in the Niger Delta and further complicates volumetric reconciliation between static, deterministic, and dynamic models.

In this paper we explore various techniques, technologies and evaluation procedures including logging and data acquisition required to properly identify and evaluate the hydrocarbon saturations in these low contrasts, low gamma ray zones. This paper will also show how saturation height function was used to estimate the ideal hydrocarbon response and volumes in reservoirs affected.

The findings in this paper will show the importance of integrating all available multi-disciplinary data to properly identify and evaluate these elusive hydrocarbon zones for proper hydrocarbon reserves volumes estimation & reservoir development.
Accelerating Nigeria's Transition to a Low-Carbon Economy: Carbon Pricing as a Strategic Option for Midstream and Downstream Industry
Authors: Ayodele Emmanuel , Oloya Obakore , Aduba Anthony
Published: August 2024

Nigeria faces significant challenges in reducing its carbon emissions and transitioning to a more sustainable economy. As an oil-producing nation, Nigeria's economy and energy sector remain heavily reliant on crude oil and gas production. However, with the impacts of climate change globally, Nigeria needs to take action to lower its environmental footprint in line with Nigeria’s Nationally Determined Contribution (NDC) as agreed at the 2015 Paris Agreement. The introduction of a carbon credit system in Nigeria signifies a substantial enhancement in value and serves as a system of incentives to encourage the reduction of carbon emissions. This system serves as an incentive encouraging industries in the midstream and downstream sectors to implement carbon emission-reduction processes. This paper investigates the procedures entailed in acquiring carbon credits within the sector industries in Nigeria, with a particular focus on the oil and gas industry. An assessment of the feasibility, applicability, expenses, advantages, and obstacles linked to the implementation of carbon credits is discussed including the utilisation of carbon credits by participants operating in the midstream and downstream sectors. This will involve the collation of publicly available emission data across the downstream and midstream, getting a broad spectrum of the emission levels, and then evaluating the feasibility of this strategy considering the costs and benefits involved. This paper emphasises the capacity of Nigerians to capitalise on innovation by demonstrating the carbon credit system as an alternative strategy to derive foreign direct investment. By examining a case study that encompasses an integrated value chain and complementary frameworks, this study demonstrates the potential for adapting this system to suit the distinct requirements of the oil and gas industries in Nigeria. This paper presents some recommendations for promoting the rapid implementation of the carbon credit system at sector-specific, subnational, and national levels in the midstream (filling stations and depots) and downstream industries. Implementation of the carbon credit system will attract foreign direct investment and promote sustainable methodologies towards the objective of diminishing carbon emissions.
Tests On Locally Sourced Mud Bio-Additives Show Better Rheological and Loss Circulation Control Properties to Enhance Drilling Performance and Guarantee Energy Supply
Authors: Nwala Stephen
Published: August 2024

Designing a drilling mud with relevant additives plays a vital role in having a successful drilling operation to sustain oil and gas supply. When a drilling fluid is poorly formulated with deficient additives, various problems such as loss circulation of drilling mud usually occur during drilling operations and this cause deferments in oil and gas supply chain. The objective of this paper is to highlight the use of locally sourced environmentally friendly bio- additives (dried sugarcane husks, dried palm kernel fiber and dried tiger-nut husks) as bio-additives for the enhancement of the loss circulation properties of a water-based drilling mud to conventional drilling mud with sodium hydroxide pH enhancer. Nine water-based mud samples were prepared with seven of these samples having varying concentration of the bio-additives as loss circulation materials. The eighth sample contained only limestone but no bio-additives while the ninth sample labelled as the control had zero concentration of the bio-additives and limestone. Tests carried out were mud density using the Baroid mud balance, viscosity using rotary viscometer, gel strength using rotational viscometer, pH using electronic pH meter and mud filtration tests using API filter press multi-unit. The various results obtained were compared with the standards as provided by API. The nine water-based mud samples prepared with varying concentration of the bio-additives showed promising results for critical mud properties such as mud density - within the API acceptable range of 8.45 – 12.00 ppg - and other properties like the plastic viscosity, apparent viscosity, yield point, mud filtrate and mud cake thickness were within values preferred by the drilling engineers as they result to lower circulating pressure that facilitate drilling processes. This paper highlights how cheap, locally sourced, and environmentally friendly agricultural wastes can become resources in mud formulation, hence need to reduce the dependence on the use of the toxic and costly chemical additives thus safeguarding the environment at large. The organic nature of these additives makes it environmentally friendly having little or no effect on the subsurface formation.
Optimization of AGO and DPK Production in an Industrial Modular Refinery Operation
Authors: Okwonna O. O. , Obuebite A. A. , Osedebamen I. I.
Published: August 2024

Optimization of automotive gas oil (AGO) and dual-purpose kerosene (DPK) production in an industrial modular refinery operation was conducted using a case study of a facility (Company A) located at Ohaji-Egbema Local Government Area, Imo State, Nigeria. The system was modelled using the Aspen HYSYS version 11.0 simulation tool. A daily input of 5,000 barrels of crude oil per day was characterized and introduced into the distillation system operating at 101.3 kPa. The distillation column consisted of 22 trays for the collection of five target products: Off-gas, Naphtha, DPK, AGO and residue. The flowrate of the target products, DPK and AGO, under the initial process conditions (Condenser: 44 oC, Stage 8: 163 oC, and Stage 16: 254 oC were determined to be 662.3 b/d and 431.40 b/d, respectively. The process was repeated at varied condenser temperatures in the range of 45 - 48 oC, and the Stage 8 temperatures were raised by 0.5 oC (163 oC -168.5 oC), while Stage 16 temperatures were increased by 4 oC (254 - 298 oC). Temperatures were recorded at each increment in condenser temperature, and the flow rates (yields) of the desired products were documented. The optimum production of AGO was observed at a condenser temperature of 48 oC, with a yield of 51.26%, at a stage 16 temperature of 270 oC (543.15k). The maximum yield of DPK was achieved at condenser temperature of 44 oC and a stage 8 temperature is 168.5 oC (441.65k), with a yield of 22.24%. Beyond the temperature of 48 oC for AGO and 44 oC for DPK, errors were encountered, and the DPK output decreased. This study identifies the precise conditions that optimizes the production of AGO and DPK, offering insights for enhanced oil refinery efficiency of the distillation process and sustainability in petrochemical engineering Top of Form.
Numerical Simulation of Heavy Oil Recovery for a Niger-Delta Reservoir
Authors: Ehibor Idahosa , Ibe Alonge , Maku Gbenga , Oyekade Suraju , Omotoso Abdulwahab , Adetula Babatunde , Goodhead Eresinkumo , Olafuyi Olalekan
Published: August 2024

This research provides a comprehensive numerical analysis of the chemical flooding process in a heavy oil reservoir located in the Niger Delta region. A thorough reservoir model was created for the case study utilizing the CMG simulator program, which includes the incorporation of geochemical modeling. Initially, the reservoir is evaluated based on its depth and the viscosity of the fluid to determine the most suitable Enhanced Oil Recovery (EOR) technique for achieving maximum recovery. Following that, various chemical injection strategies were implemented employing alkali, surfactant, and polymer to determine the primary chemical agents accountable for the enhanced recovery factor. The reservoir case study is a clastic reservoir that has a depth of 7400 ft and a pay zone thickness of 12 ft. The Petrel software was utilized to construct the stationary representation of the reservoir, which was subsequently imported into the CMG 2021 simulator for comprehensive dynamic modeling and simulation. A historical match of the reservoir model was performed to accurately align it with the measured field data obtained from the reservoir. In order to accomplish this purpose, different control variables were modified within an operational restriction to obtain a history match of field output rates. The feasibility of the injection schedule was assessed at the pre-evaluation stage in order to choose the most efficient injection plan from both a technical and economic standpoint. The injection scheme comprises Polymer injection, Alkali-Surfactant injection (AS), Alkali-surfactant-polymer (ASP) injection, and nanofluid technology. In order to minimize the bypassing of crude oil, a pre-flush and post-flush water flooding technique was implemented in these injection schemes. In the post-evaluation step, the injection technique is optimized to maximize the net present value (NPV) of the project. The initial simulation findings suggest that injection sequences including polymer are the most effective due to its viscosity and its capacity to enhance oil movement in the reservoir. By combining Polymer injection with a sequence of AS flooding and pre-flush and post-flush water injection, the recovery factor from the reservoir was maximized. This was achieved through the combined benefits of high viscosity polymer mobility and the lowering of interfacial tension (IFT) and alteration of wettability caused by AS flooding. In summary, the introduction of a buffer polymer chemical slug following the initial pre-flush waterflood demonstrated the most favorable production performance, resulting in a recovery rate of up to 20%. An economic study of this injection plan was conducted by taking into account oil prices that are contingent upon the current market conditions.