bluuebunny/crossref_metadata_2025 huggingface dataset:
Effects of Carbon Dioxide and Liquified Petroleum Gas Mixture on Minimum Miscibility Pressure for Carbon Dioxide Storage and Enhanced Oil Recovery
Authors: Al_Ani M. , Sidek M. A. , Jaafar M. Z. , Agi A. , Gbonhinbor J. , Ridzuan N. , Mahat S. Q. A. , Yakassai F. , Ngouangna E. , Oseh J.
Published: July 2023

The increase in carbon dioxide (CO2) and other greenhouse gases emission into the atmosphere has resulted in global warming and climate change. CO2 capture and storage are viable option to mitigate against this problem. Hence, in this study the potential of CO2 storage in the Malay Basin for enhanced oil recovery (EOR) was evaluated using Eclipse. Likewise, the effect of the synergy between CO2 ratio and liquefied petroleum gas (LPG) mixture on optimum miscible pressure (MMP) for CO2 storage and CO2-EOR process was investigated. The results indicate that 137 MMSCF of CO2 can be stored through this process. Consequently, the total amount of oil production was within range of 190 MMSTB to 230 MMSTB. Besides, the volume of oil production through the process of CO2-EOR increased with increase in injection of CO2. Injection of CO2 and LPG mixture show that MMP decreased from 1,910 psi to 1,700 psi. Therefore, it can be concluded from this study that CO2-EOR process followed the multiple contact miscibility scheme whereby the residual oil was swept towards the producing wells.
Effect of Temperature and Particle Exposure on Hydroxyapatite Nanoparticles on Wettability Alteration of Oil-Wet Sandstone
Authors: Ngouangna E. , Jaafar M. Z. , Anam M. N. , Agi A. , Gbonhinbor J. , Ridzuan N. , Mahat S. Q. A. , Yakassai F. , Oseh J. , Al_Ani M.
Published: July 2023

Nanofluid treatment is being developed to improve oil recovery and reduce residual oil entrapment in sandstone reservoirs. Nanoparticles for enhanced oil recovery (EOR) at ambient conditions have shown good potential in recent research. The efficiency on EOR has been found to be significantly influenced by nanofluid composition, exposure and time. However, there is a serious lack of knowledge regarding the influence of temperature on nanofluid performance. The effects of temperature, exposure, time, and particle size of hydroxyapatite nanoparticles (HAP) on the wettability alteration of an oil-wet sandstone were thoroughly investigated, and the stability of the nanofluids was equally examined. At higher temperatures, it was discovered that nanofluid treatment is more effective, with nanoparticle size having little or no influence. The sandstone surface mechanically absorbed most nanoparticles in an irreversible manner. The HAP nanofluid was still effective at high temperature reservoir condition and is herein proposed.
Techniques for Investment Decision Making for Oil and Gas Assets
Authors: Obidike Peter , Nwosi-Anele Adaobi
Published: July 2023

Oil and gas will remain a critical source of energy in the global energy mix and will continue to command attention in investment decisions given resource rich countrie's dependence on hydrocarbon for revenue, even with the energy transition.

The techniques for investment decision making vary, depending on the drivers of the decisions. Techniques for investment decision making can be both quantitative and qualitative. Most techniques will start with quantitative analysis but ultimately end up depending on qualitative views from project teams and top management decision makers as they consider factors beyond quantitative evaluations such as political and strategic views.

Quantitative evaluations involve the use of economic indicators, stochastic evaluation, and prevailing market conditions for the assessment of profitability of oil and gas projects. The economic evaluation results influence the risk behaviour of investors and decision makers.

The qualitative evaluations consider the business drivers, stakeholder's perspectives, including the government in most cases. Other considerations for the qualitative assessment include things like risk appetite, assessment of project locations and energy transition policies. These areas of considerations highlight the need for investment decision making to be guided by quality decision analysis that can help put things in the right perspective and guarantee quality decisions even if it is impossible to guarantee the outcome of such decisions.

In this paper we review quantitative and qualitative decision-making techniques from literature. We also present practical cases where qualitative evaluations guide project teams to choices beyond the quantitative evaluation results.
Eliminating Associated Gas Flares in The Nigerian Stranded Marginal Field Oil Fields: The Otakikpo Field Strategy
Authors: Akinyemi Johnson , kala-otaji Tamunotroko
Published: July 2023

The Otakikpo marginal field was carved out of OML 11 and is situated in the southern part of the license. The field was discovered with Otakikpo-02 in 1983 and was further appraised with Otakikpo-03 in 1986. The wells encountered hydrocarbons in 4 stacked oil and gas bearing sands (C5000, C6000, C7000 and E1000). The field is operated by Green Energy International Limited (GEIL).

The field currently produces ~10,500 bopd with significant associated gas (AG) production from the wells with average GOR of ~1000 scf/bbl. Compositional analysis shows that the associated gas is rich in C3 – C4 components (~ 8%) and C5 – C7 (~ 3%) making it ideal for NGLs (LPG and condensates) extractions.

Most natural gas utilization projects require securing constant gas production contracts for between 10-20 years and for constant rates > 50 MMSCFD. However, the Otakikpo field, the associated gas reserves do not meet this threshold and the production profiles are at best unpredictable.

To address these issues, an innovative strategy is required to accelerate reduction in the field's AG flaring. A qualitative and quantitative screening of the various gas utilization concepts against some critical decision drivers (AG production profile, scalability, CAPEX) led to the recommendation of a modular LPG extraction plant for the heavier components of the AG and Gas to Power for the lean gas.

The conventional approach of piping gas from a remote field needs to be replaced with a less orthodox technique of "bringing the plant to the gas". This eliminates the need for expensive pipeline and compression since the facility is within the Otakikpo field flow station. Furthermore, a modular scalable strategy with small footprint plant that is quick to deploy and easy to relocate was recommended as the best solution for the field.

The Operator successfully commissioned the 12MMSCFD modular LPG extraction plant and 6MW power generating plants. This scale of modular LPG plant will be the first to be installed in the country. This strategy could be adopted by other small fields in addressing AG flares caused by stranded pockets of gas located in oil fields in the Niger Delta thus supporting the Government's aspiration of eliminating AG flares.
Conceptualizing the Otakikpo Onshore Terminal: The First Indigenous Onshore Terminal
Authors: Akinyemi Johnson , Kala-Otaji Tamunotroko
Published: July 2023

The Otakikpo field development activities commenced in 2015 with the re-entry and completion operations on Otakipo-02 & 03 wells and the installation of a 10kbpd processing facility. Due to its proximity to the shoreline, an amphibious production and evacuation methodology was implemented. This consists of batch production into onshore tanks, a subsequent evacuation into offshore shuttle tanker via an installed 6" Km offshore pipeline and final transportation to a 3rd party FSO facility. The first phase of the field development was completed in 2017 and production declined from ~ 6500 bopd to ~ 4000 bopd by 2022.

Green Energy successfully executed phase 2 of the field development by drilling and completing two new development wells, Otakikpo-04 and -05 wells in 2022 and field production increased to circa 10000 bopd. The production facilities limit the field production to 12,000 bopd while the evacuation infrastructure could only effectively handle about 14,000 bopd. Moreover, the field's evacuation cost is very exorbitant mostly from the cost of hiring marine vessels (2 gunboats, 2 shuttle and 2 tugboats) and paying for CHA charges at 3rd party terminal. At lower production rates, the cost per barrel will be unsustainable.

It is for this reason that the Operator conceptualized a phase 3 development strategy to develop and install an efficient evacuation/export strategy and thus reducing overall OPEX $/bbl. It also plans to make the Otakikpo field a crude processing and export hub in the Eastern Niger Delta area. To achieve this, the operator plans to construct an onshore terminal and export infrastructure very close to the field. This consists of a scalable onshore terminal with an initial 750,000 barrels of oil storage capacity located within the field with a 360,000-bpd pumping and metering capacity for loading tankers. It also includes a 20" × 23km offshore export pipeline connecting the terminal to an unmanned single point mooring (SPM) crude offloading system. The terminal is expandable to store circa 2 million barrels of crude with a daily processing capability of 250,000bopd.

The proposed Otakikpo onshore terminal is conceptualized as a national infrastructure with potential to unlock significant stranded national reserves. It will be the first new onshore terminal in Nigeria in over 50 years, and first to be non-IOC owned and operated. Moreover, the terminal is expected to create significant value for the over 20 stranded marginal fields that are in proximity to terminal which would benefit from access to readily- accessible, cost effective and fit for purpose evacuation infrastructure.

This paper aims to highlight the justifications for the Otakikpo onshore terminal, lessons learnt during the conceptualization and design stages, status of the project, opportunities for future expansion and its potential role in the energy security of the nation in future.
Application of Lignin Polymeric Nanofluid as a Chemical Enhanced Oil Recovery Agent at Reservoir Condition
Authors: Al_Ani M. , Sidek M. A. , Jaafar M. Z. , Agi A. , Gbonhinbor J. , Ridzuan N. , Mahat S. Q. A. , Yakassai F. , Ngouangna E. , Oseh J.
Published: July 2023

Surfactant flooding constitutes part of the relevant enhanced oil recovery (EOR) technologies desirable for Malaysian oilfields. However, the high cost of synthetic surfactant production, high toxicity, susceptibility to high salinity reservoir condition, high adsorption rate and the strict regulation laid by government agencies in different countries has limited the growth of synthetic surfactant market in the post Covid-19 era. To solve this problem, the non-petroleum-based (biomass) surfactant can be used to replace the petroleum-based surfactant. Therefore, in this study lignin polymeric nanofluid (LPNF) was synthesized from sago bark using the method of ultrasonic assisted nanoprecipitation for EOR application. Besides, the surface morphology, functional groups, purity, structure and thermal stability of the lignin nanoparticles was determined using transmission electron microscopy, Fourier transform infrared spectroscopy, high pressure liquid chromatography, nuclear magnetic resonance and thermogravimetric analysis, respectively. The interfacial tension (IFT) of the formulated LPNF at oil-water interface was determined via a Kruss tensiometer. Thereafter, the ability of LPNF to alter the wettability of oil wet sandstone core was determined using a drop shape analyzer. TEM results indicate that lignin nanoparticles of size range 10-23 nm were produced. The zeta potential of -34 mV shows long-term stability of the nanofluid. The LPNF altered the wettability of the sandstone core from oil wet (133.3°) to water wet (10.2°), decreased IFT thereby indicating high propensity to increasing oil recovery at reservoir condition.
Overcoming Non-Technical Challenges in Well Abandonment – A case study of a field in the Niger Delta
Authors: Okonkwo Ngozi , Agbogu George , Olowu Babajide , Bougha Arthur , Reginald-Ugwuadu Onyinye
Published: July 2023

There is a new drive on well abandonment in Nigeria. Numerous technical challenges arise while safely delivering abandonment wells often due to missing & inaccurate historical data considering that some of the wells were drilled over 60 years ago. This challenge alone makes it an easy oversight from most rig and office-based teams to focus more on the technical challenges while losing sight of an equally important & often understated factor namely non-technical issues.

The well objective of decommissioning/abandonment is to install permanent barriers to effectively isolate the hydrocarbon bearing reservoirs from the freshwater reservoirs and the surface in an environmentally safe manner and restore the surface location as close as possible to its original state. What these objectives imply is that benefits (local employment during well intervention, freedom to operate dues and government entitlements as producing communities) are no longer accessible to the local host communities which bring forth a dimension that often times acts as a spanner in the works of efficient & effective abandonment operations.

This paper will address in detail the challenges encountered during a recent well abandonment campaign spanning 5 wells in the same calendar year, how the team effectively managed the non-technical issues and continuously improved from high NPT recorded in the 1st well to less than 10% at the end of the campaign without any safety incident. In this new era of focused abandonment in the Nigeria oil industry empowered by recent PIB signed into law, the knowledge and learnings from this project will help other operators who will undergo mandatory abandonment of wells in near & far future to appreciate and plan for these challenges.
A Sustainable Pathway to Achieving Operational Efficiency While Reducing Carbon Emissions Using Remote Operations and Drilling Automation
Authors: Umeonaku Loretta , Aluu Ben , Okafor Kenechi , Atakpa John
Published: July 2023

In recent times, remote operations in drilling and wellsite activities have evolved from a nice-to-have service to a vital solution for delivering world-class logging and well placement management in the oil and gas industry. The drive towards remote operations accelerated during the Covid-19 pandemic where it was beneficial to operate with minimal personnel in order to limit their exposure. Moreso, with 2050 being about three decades from now, energy companies are strengthening their commitments to achieving net zero global carbon emissions in solidarity with the Paris agreement of 2015 geared at reducing the impact of climate change. It is safe to say that remote operations services are poised to change the future of oil and gas operations as more operators jump on board and see the true benefit of remote operations from a safety, cost-saving, and carbon footprint reduction viewpoint.

In May 2020, as part of Baker Hughes Drilling Services Nigeria's strategy for carbon reduction and carving a road map to automated drilling, the first Remote Operations centre in Sub-Saharan Africa was launched. Equipped with robust high-speed data links to connect to multiple rig sites enabling 24/7 monitoring and control of multiple drilling operations. The centre provides real time unified data streaming and visualisation enabling enhanced well monitoring and management. In addition, it is manned by highly experienced drilling professionals who collaborate with various subject matter experts to optimise overall service delivery.

This paper demonstrates the significant value of adopting remote operations in delivering optimized drilling and logging services. Two case studies illustrating the approach and strategies utilised in safely and flawlessly delivering two wells remotely will be elucidated. The technicalities deployed to save one of the operators from shutting down in the middle of the Covid-19 pandemic, the re-manning model utilized, and workflow schematics will be discussed. Finally, it quantifies the amount of carbon footprint reduction achieved, lessons learnt, and optimization opportunities.
Net-To-Gross Uncertainty Impact in Field Development Planning: A Deltaic Reservoir Example
Authors: Manuel Tekena , Arochukwu Elias , Nwonodi Chike
Published: July 2023

Net-To-Gross (NTG) is the ratio of pay rock volume to the gross rock volume estimated over an interval used to compute hydrocarbon-initially-in-place (HCIIP). Identifying NTG as a series of discrete data points along the well path where the rock is ascribed as reservoir (NET = 1), or non-reservoir (non-NET = 0) based on a suitable cut-off estimated from a combination of petrophysical logs is a first step. In a deltaic setting, prevailing depositional processes result in inherent vertical and lateral variability with the effect that the determination of NTG is scale sensitive and interval dependent. This reality imposes a requirement of deliberate focus in 3D NTG modelling to preserve the depositional heterogeneity and ensure that any integrated reservoir modelling effort is geologically representative. This paper discusses different practices in the use and upscaling of NTG from well data and distribution in a static model, by comparing three approaches: (1) upscale and distribute using Sequential Gaussian Simulation (SGS) biased to facies, (2) upscale and distribute independent of the facies model but biased to established NTG regional trend, and (3) generate a discrete model based on a combination of the facies model and NTG data from the wells. The best method, which is still a simplification of reality, will be one where the model can rightfully predict NTG in undrilled areas and assess the impact on recovery estimation. Assessing these methodologies using a mature field in the coastal swamp depobelt in the Niger delta helps build a case for model simplification in an adjacent partially appraised field in the same depobelt. Thus, providing a simplified approach and clarifying insights on the conundrum of utilizing discrete NTG ‘logs’ to build a continuous property that is useful for HCIIP estimation but has minimal impact in the dynamic behavior of the reservoir.
Strategic Reservoir Management: An Integrated Approach to Production Restoration and Optimization
Authors: Pepple Precious , Tafida Maryam , Chukwuma Akaba , Mogbo Chinwendu , Udo-Etuk Aniekan , Okeke Chinweike , Nwachukwu Chukwuemeka , Yaboh Dengie , Itene Richard , Adeeyo Yisa
Published: July 2023

A large percentage of the oil and gas production around the world today comes from mature hydrocarbon reservoirs. In turn, these mature assets supply the bulk of the world's energy. In Nigeria, most of these assets are situated in volatile environments. Managing these assets is therefore a pivotal aspect of ensuring Nigeria meets its OPEC energy supply obligation.

Strategic Reservoir Management (SRM) is a robust integrated production restoration and optimization approach that seeks to drive value from existing assets by ensuring economical/optimal and safe evacuation of hydrocarbon from the reservoir to surface tanks. The BNT Field Management Team seeks to leverage on SRM best practices to identify Short Term and Long-Term opportunities that will enable the asset to achieve its oil and gas production aspirations and enable Nigeria to continue to fulfil its oil and gas production obligation.

Some of the BNT field's most productive oil and gas reservoirs are the prolific X1000A and Y9500A reservoirs. Many third-party interferences with flowlines and difficulties with asset integrity have significantly delayed output from the oil conduits and reduced value. Based on the outcome of an integrated well, reservoir and facility review and candidate selection process, BNT002 well was chosen as the first well to be restored to production. This paper presents an integrated approach for the restoration and optimization of a surface comingled oil well to add ca. 4.15 Mbopd and develop ca. 6.00 MMstb. BNT hydrocarbon streams are evacuated via two facilities – BN NAG Plant (450 MMscf/d capacity for gas and a liquid handling capacity of 10 Mbbl/d) and BN flow station (30 Mbpd capacity).
Sustainable Host Community Development – An Enabler for Energy security & Economic development in Nigeria
Authors: Chukwu Engr. Emeke , Offor Chinyere
Published: July 2023

Till date, Nigeria is heavily dependent on revenue generated from oil and gas to finance its annual budget to provide public goods and services beneficial to its citizenry. The 2022 budget reflects that 31% of Federal government earnings will be result from oil and gas. Despite the push to diversify her economy, the stark reality remains that oil and gas sales is an influential factor to enabling economic development in Nigeria. More so, countries such as Saudi Arabia and Norway have utilized oil and gas wealth as the basis to invest in other sectors and promote diversification. However, Nigeria's goal of Energy security and economic development is likely not to be achieved as she battles with crude theft plaguing her ability to evacuate crude to her customers. Nigeria National Petroleum Company Limited (NNPCL) reported a loss of 470,000 bpd of crude amounting to an estimated 0.4 trillion naira monthly due to oil theft. The annualized estimate of 5.2 trillion-naira loss represents a staggering 30% of Nigeria's 2022 budget expenditure of 16 trillion naira. With other associated impacts to Nigeria, there is an imperative to deal and ultimately put an end to this looming menace. This study focused on addressing the crude oil theft through sustainable Host community engagement and development.

A review of the factors promoting crude oil theft in Nigeria was performed. The study analyzed the production loss data over a decade and positively correlated it with economic development indicators such as poverty index, inflation, per capita income. The impact on the host community was studied.

The results showed that the disenchantment of host communities (despite being key stakeholders in the oil and gas value chain) necessitated their little to no responsibility for protecting oil & gas assets and preventing the perpetration of crude oil theft.

The study developed and proposed a "Host community development plan" which if administered with provisions already existing in the Petroleum Industry Act could revolutionize the Oil & gas industry by promoting increased ownership & fostering collaboration towards achieving Energy security & Economic development in Nigeria.
Development of an Automobile Adulteration Indicator System
Authors: Olotu O. O. , Isehunwa S. O.
Published: July 2023

Automobile users in the city are battling a serious problem these days with adulteration of Fuel. With an increased number of petrol pumps dispensing ‘unfit’ fuel, ‘dirty fuel’, consumers complain that vehicles are now faced with a range of glitches including poor ignition, reduced mileage and even jammed engines. Apart from causing inconvenience, this has also added to the maintenance cost of automobiles, say users, with the price of spare parts, especially engines skyrocketing by the day. Adulterated petroleum products in automobiles contributes to auto malfunctions, urban air pollution, health hazards and has continued to increase in Nigeria due to scarcity of products. Laboratory analyses normally conducted by regulatory agencies and some end - users for routine assurance of the petroleum products are not competent enough to address the issue.

To effectively technically detect petroleum products adulteration in an automobile at real-time with the use of an indicator system on the dash board of the automobile, the technology of an electronic device, adulterate meter is being incorporated. The said indication system having an input are supplied by the ignition system. The design is such that as soon as the fuel sample torches the base of the fuel tank, or a change in chemical composition of fuel purity, an electrical signal, mostly a load cell sensor or a voltage signal is connected to the sensor situated at the base of the fuel tank. The output signals from the detector circuit are conditioned to produce outputs which can be measured with color display and alarm.
Investigation of Suitable Slug Models for Polymer Alternating Gas Deployment (Niger Delta Case Study)
Authors: Dennar L. N. , Amro M. , Onu C.
Published: July 2023

Core Flood analysis is one of the processes that can be deployed towards investigating the property changes associated with the reservoir post polymer flooding. The core flooding system is a test to determine rock permeability and how a core sample will interact with various fluids. The core sample is placed in a rock core holder. Once the core is inserted in the core holder, the outer surface is pressurized to simulate the same reservoir pressure created by the overburden in the reservoir.

A test fluid is subsequently passed through the core and the flow rates and pressure drops across the system is measured. From this data, various parameters are measured including unsteady state liquid relative permeability and single-phase permeability, EOR tests, Residual Resistance Factor (RRF) and Resistance Factor (RF). The mobility of water to the mobility of a polymer solution under the same conditions is defined as the Resistance Factor (RF) (Jennings et al. 1971)1. This is a good index in the determination of the success of a good polymer flood (see the equation below). Kw and Kp are water and polymer relative permeabilities and µw and µp are water and polymer viscosities, respectively. RF = KwKpμpμw

Residual Resistance Factor (RRF) is another useful parameter which is defined as the ratio of the initial water mobility to the water solution mobility after polymer flooding (Jennings et al. 1971)1: where wi indicates the water permeability or viscosity at initial condition (before polymer injection) and wa is the water solution permeability and viscosity after polymer flooding. The RRF is a quantitative indication of the reduction of water mobility which controls the water fingering process due to water injection after polymer flooding (Jennings et al. 1971)1.RRF = KwiKwaμpaμwi

This study investigated the RF and RRF associated with a Niger Delta reservoir post Polymer Alternating Gas (PAG) flood which was subsequently instrumental in the selection of an optimal (PAG) slug model. Biopolymer (Xanthan) and Synthetic polymer (Polyacrylamide) were used as the base fluids. Polyacrylamide which is a copolymer of acrylic acid/acrylamide and Xanthan has been used extensively in enhanced oil recovery (EOR) processes. High molecular weight polyacrylamide strongly increases the water viscosity and thus decreases the water–oil mobility ratio in water-flooding.

The Resistance Factor and Residual Resistance Factor for single phase saturations and slug deployments investigated gave interesting outcomes for each polymer type. PAA gave a more favorable outcome as indications from the flooding suggests the existence of high injectivity associated with the Xanthan flooding. Results from the different Slug scenarios suggest that using smaller slug model would not be favorable for the deployment. Larger slug models yield better RRFs. A combination of larger slugs of CO2 + Polymer gives better results and enables greater injectivity.
Resolving Conflicting Recommendations in Investment Analysis
Authors: Akinpelu L. O.
Published: July 2023

Investment worth or investment performance metrics guide us in making investment decisions. These metrics address specific aspects of investments such as value creation, investment efficiency, risk exposure and risk mitigation amongst many considerations. With the complexity of most investment decisions and the size and scale of many investments especially in the Oil & Gas Industry, it is not enough to look at one dimension of investment. For instance, while most people will look favorably at value creation, which is the central premise of most investment decisions, in the context of limited capital, it is also relevant to factor into decision making, the cost of such value created. In other words, net present value (NPV) which is the time-tested value creation performance metric for investors, will not suffice for most current managerial considerations, particularly when comparing two or more investments. How much value is created is usually juxtaposed with the question: at what cost? In which case, analysts must, of necessity present to Management or the Project Decisions Board, NPV along with other performance metrics, usually the discounted profit to investment ratio, (DPI) and Rate of return (ROR). DPI is value creation per unit of investment or a measure of investment efficiency. The two measures complement each other and expand managerial insights as to the efficacy or otherwise of the investment(s) under consideration. In contemporary investment analysis, more emphasis is placed on investment efficiency reflecting investor preference for ever higher return on capital employed. If the two measures each recommend a particular investment over another, then the decision to invest is straight forward. The problem arises when one metric recommends one investment and the other metric recommends another - a situation that we describe as conflicting recommendations. Which investment to choose will require factoring into the investment decision several considerations beyond just value creation and investment efficiency. Considerations such as available capital, the company's short- and long-term business objectives, other potentially available opportunities all come into play.

This paper addresses issues arising from conflicting recommendations. We will highlight this problem by considering a simple example of two investments A and B of the same duration of five years and slightly different investment levels. We will limit our analysis to two popular investment metrics - Net present value (NPV) and discounted profit to investment ratio - DPI. The analysis presented is mainly deterministic and the investment opportunity space is limited to these two investments.
Practical Approach to Greenhouse Gas (GHG) Emissions Reduction in Stranded Oil Producing Assets – Technical Feasibility Safeguards 15MMscf/d Gas Supply
Authors: Muzan Eelah , Ogbunude Basil , Chiroma Barka , Maxwell-Amgbaduba Sunday , Udobata Uchenna , Okereke Onyedikachi
Published: July 2023

Global climate change concerns and the need for decarbonization of the energy sector make it imperative for oil and gas companies to reduce greenhouse - gas (GHG) emissions in their operations. In Nigeria, the Federal Government Gas Commercialization Programme (FGCP) stipulates fines for routine flaring above specified thresholds in Nigeria.

Most oil wells in the Niger Delta are produced with Associated Gas (AG) and high gas-oil-ratios (GOR) wells result in significant flares and attendant GHG emissions where there isn't gas gathering facility to process the AG. In addition, the remoteness and unavailability of nearby gas markets in the locations of some assets in the Niger Delta threatens the economic viability of standalone AG processing facility in these assets. Based on these limitations, an optimal solution of re-routing producing wells to the nearest available gas processing facility was assessed for Alpha & Beta Fields.

Alpha & Beta Fields commenced production in 1973 without AG processing. Oil production peaked in 1975 at ca. 50kbopd with current production at 11kbopd. The producing reservoirs have a combination drive mechanism with both an active aquifer and a gas cap. Consequently, the wells completed in these reservoirs have a GOR ranging between 500 – 2000scf/bbl and about 15-20MMscf of gas is flared from the facilities daily. To manage the flare volume, the oil wells are typically beaned down to produce on restricted rates, resulting in production deferments.

This paper outlines the technical assessments using Integrated Production System Modelling (IPSM) with the Petroleum Expert IPMTM tool to confirm the viability of bulk flowing the wells from the Alpha & Beta Fields to the nearest facility with AG gathering capability to manage flaring, reduce GHG emissions and create value by unlocking additional gas and oil production. Re-routing to the 120MMscf/d capacity AG compression facility, located ~30km from the fields required the isolation of the wells from the existing delivery line and installation of multiphase header and flowmeters.

Results of the analysis indicated that the wells could deliver the expected production to High Pressure (HP) Separator in the Central Processing Facility (CPF). In addition, the wells are expected to sustain production with peak gas rate of 15MMscf/d. The project is expected to contribute to the company's net-zero emission ambition through reduction of GHG emission from flares and combustion engines, enable OPEX savings associated with flare penalties and maintenance activities while providing revenue from unlocking oil production as well as the monetization of the produced gas.
Performance Evaluation of Nanocellulose Synthesised from Yam Peels as a Fluid Loss Additive in Water Based Mud
Authors: Ibrahim Khadijah , Nzerem Petrus , Salihu Ayuba , Gimba Abdullahi , Ogolo Oghenerume , Otedheke Ajiri , Adamu Rabiatu , Karofi Aisha
Published: July 2023

Drilling fluids play a variety of roles in order to achieve a smooth and cost-effective drilling operation, the most important of which is their ability to seal permeable walls of the formation through the formation of a desirable mud cake, thereby reducing fluid loss. This study is targeted at evaluating the performance of nano cellulose, cellulose microfibrils synthesised from yam peels as a fluid loss additive and also its effect on the other properties of the drilling mud. The use of nano-cellulose is due to smaller particles forming better impermeable packing that will plug the permeable pore of the mud cake, as well as its ability to hold water. The nano cellulose was synthesised using bleaching, alkali treatment, and acid hydrolysis, and its quality was assessed using Fourier Transform Infrared Spectroscopy (FTIR) and Scanning Electron Microscopy, which confirmed the removal of some non-cellulose components as well as changes in surface morphology. The results of the experiment revealed that nano cellulose had an effect on the pH, rheological properties, and filtration properties of the drilling mud. The results also show that adding 1.5 g of nanocellulose reduced fluid loss by 8.13 %, and thus it can be concluded that yam peels nanocellulose will be an effective additive at higher concentrations compared to the Carboxyl Methyl Cellulose, a commercial additive.
Integration of Artificial Intelligence with Economical Analysis on the Development of Natural Gas in Nigeria; Focusing on Mitigating Gas Pipeline Leakages
Authors: Ezechi C. G. , Okoroafor E. R.
Published: July 2023

With Nigeria's massive proven natural Gas reserves and potential to provide a sustainable and economically viable system, a significant challenge has been the need for development strategies that enhance safety, growth, and investments in the gas sector. To tackle these challenges, the data generated in oil and gas, which is a valuable tool, has to be harnessed for stakeholders to implement life-changing solutions. The Nigerian economy has faced a significant drawback in the gas transportation and storage sector. The challenge in gas transportation can be seen in gas pipeline leakages which have resulted in the loss of lives, properties, and the country's revenue. Thus, early leak detection gas of pipelines remains critical for economic and safety reasons. This paper uses artificial intelligence to build models that utilize the available gas flow data to detect potential gas leakages across the pipeline. Machine learning algorithms which include Recurrent Neural Networks, and K-nearest neighbourhood are built and trained with operational data to derive the optimal learning model. Also, each model's performance metrics were evaluated to measure the model's accuracy and precision. Furthermore, an economic model is then developed to show the monetary benefits of implementing AI solutions to gas leakages. Thus, we provide a stepwise comparative analysis of the gas revenue, gas leakage detection cost, and the cost of providing an answer from an AI-based architecture to a non-AI-based one. The results showed that recurrent neural network outperforms the K-nearest neighbors in leak detection in pipelines as a result of the framework of neural network that allows the algorithm to learn without human supervision a and sift through the data set and label the data point. However, all the machine learning models possess high reliability. The accuracy and reliability of these models upon economic analysis proved to be a cost-effective solution lowering cost and increasing revenue. These models can be employed by companies and engineers to tackle the problem of pipeline leakage detection.
Realizing Value Through Focused HPHT Wells Intervention – The GAMMA Story
Authors: Obakhena O. F. , Biambo T. G , Alli-Oluwafuyi J. , Anijekwu C. , Ogbodu S. , Okolomma E. , Braimah O. , Eke K.
Published: July 2023

Gamma field, a brown onshore field in Niger Delta, Nigeria, has been producing oil and gas from normally hydrostatic pressured reservoirs for over 40 years. In 2017, a drilling campaign, targeting two HPHT natural gas reservoirs, kicked off as part of a gas development project to supply gas to the export gas market. This was the first of its kind in SPDC with seven wells planned to be drilled in a campaign mode to optimize project cost and timing. Being the first experience of drilling and completion of HPHT wells, there were several challenges encountered. Drilling challenges includes stuck pipes and loss of BHAs leading to several hole sidetracks. Completions challenges encountered were sustained high casing head pressures due to material corrosion and inflow impairment due to drilling and completions fluids used.

A very significant challenge was the loss in well productivity of these high-rate HP gas wells due to the heavy barite-weighted drilling mud used to drill the reservoir section (for well control) was also left in hole for over 6 months before well clean up and production. Therefore, there was a mixed outcome from the drilling campaign, with over 50% of the wells experiencing a potential loss (the wells were tested to rates of 20 – 85MMscf/d against an expectation of over 100MMscf/d.

The loss of productivity was adjudged to be due to the caked barite across the reservoir section below the Formation Isolation Valves (FIV) which plugged the sand control screens, resulting in very high drawdowns. Furthermore, two of the wells produced with high casing head pressures (High A-Annulus pressures) equaling the Maximum Annulus Allowable Surface Pressures (MAASP) of the wells and were closed in for well integrity reasons.

As part of well productivity restoration, some premium bespoke cocktail of stimulation chemicals was selected (Imbazi, Oyeintonbra, et al, 2019) and with an effective well intervention program was designed and executed by joint team of local and global Experts. Currently, 5 of the 7 originally planned wells have been restored post well intervention and are producing above expectation.

This paper discusses how the value of these wells are ultimately realized, what was done, what was achieved and how the learnings from the first drilling campaign were incorporated to achieve better results in later wells.
Dimensionless Pressures and Derivative Distribution of Two Interfering Horizontal and Vertical Wells in an Infinite Acting Reservoir
Authors: Emumena E. , Adewole E. S. , Ojah M. G.
Published: July 2023

One of the major guide in achieving a prolong oil production is the accurate description of the reservoir system. This description is essential in all aspects of petroleum engineering and is achievable through reservoir characterization by analytical models based on dimensionless pressures and derivative distribution of two interfering horizontal and vertical wells in an infinite acting isotropic reservoir. In this work, the Gringarten Model and solution to the dimensionless diffusivity equation using Laplace transform and modified Bessel equation is utilized in deriving a solution to the problem of interference testing of an active horizontal well in the presence of an active vertical well located in an infinite acting isotropic reservoir. The Excel and Python software were deployed to compute dimensionless pressures and derivative by the use of superposition principle. Larger magnitudes of dimensionless pressure and derivative would indicate higher oil production for any well design. The work investigates the effects of separation distance between active and observation wells, well lengths and wellbore radius on the pressure response at the observation well. The influence of the number of active wells, Locations and timing of activities of active wells on the pressure response at the observation well has also been investigated. The results obtained from this work can be applied in well placement and spacing decisions during field development as well as in understanding the positive or adverse effects caused by nearby wells during well tests.
Application of a Simulation Approach to Develop Erosional Velocity Correlation for Wells in Oil Rim Reservoirs in the Niger Delta
Authors: Ukpong S. E. , Livinus A.
Published: July 2023

Erosion is a major issue that could be encountered in the oil and gas production and transportation facilities. Oil and gas companies have always tried to develop proper methods to limit erosion to an acceptable level. For many years now, many oil and gas field operators have adopted the America Petroleum Institute recommended practice 14E (API RP 14E) equation to estimate the erosional velocity. Unfortunately, the C-factors in the API RP 14E equation has been generalized, even to conditions and applications where it was invalid, resulting to varying degree of success.

In this work, thousands of well performance simulations were carried out to generate stable operating production rates using data from vertical wells in oil rim reservoirs in the Niger Delta. Approximate model was then developed for erosional velocity calculation using the least square regression method. Furthermore, the developed model was compared with other existing erosional velocity correlations. The new model can be helpful for the design of production facilities for oil rim reservoirs.
Addressing Energy Availability, Accessibility and Affordability Amidst Energy Transition in Africa: Ghana's Outlook
Authors: Oppong Riverson , Asante Ben , Ackah Ishmael
Published: July 2023

In 2015, the UN adopted 17 Sustainable Development Goals. These goals seek to tackle some of the world's greatest challenges by 2030. Goal 7 aims to "ensure access to affordable, reliable, sustainable and modern energy for all". This is an ambition that implies changes in the way energy is produced, accessed, and used.

The research evaluated all five scenarios as presented by the energy transition committee: i. Business-as-Usual Scenario (BaU); ii. Transition Scenario 1 (T1); iii. Transition Scenario 2 (T2); iv. Transition Scenario 3 (T3); and Transition Scenario 4 (T4). Reliability and adequate supply of the sources of the base loads were analyzed; advantages and disadvantages of the scenarios were drawn; emission consequences from the scenarios were also simulated; cost of transition and cost of generation based on the estimated CAPEX and OPEX were modeled.

The energy transition scenarios considered the use of Carbon Capture, Utilization and Storage (CCUS) technology; use of compressed natural gas as base load, electric, hydrogen fuel cell vehicles; sustainable aviation fuel; efficient energy transformation processes; and efficient end-use appliances. Another scenario considered everything under the case above and includes the use of nuclear for power generation.

This research tested the availability, accessibility and affordability of the five main energy transition scenarios Ghana is considering for its transition plan and applied fuzzy logic in selecting the best options.
Impact of Incident Reporting on Operational Risk Management and Accident Prevention in FPSO Operations in Nigeria
Authors: Agbadiba Isioma , Maduagwu Daniel Nduweze
Published: July 2023

The exploration and production of oil and gas in deep waters is very challenging and comes with high operational risks especially in offshore rigs and Floating Production Storage and Offloading (FPSO) facilities. The incidents associated with the operation of an FPSO could be catastrophic with ripple effects that involves socioeconomic, environmental, health and reputational damages as experienced in the British Petroleum Deepwater Horizon accident in the Gulf of Mexico in 2010, which has been described as one of the most catastrophic accident in the history of the oil and gas industry in the US, considering the huge lost recorded. Therefore, the purpose of this paper is to reveal how effective incident reporting can enhance risk reduction and accident prevention in offshore oil and gas facilities with emphasis on the FPSO facilities in the Nigerian Gulf of Guinea and beyond. Mix method of collection data was use, and qualitative and quantitative data were obtained through literature review; semi-structured interviews and online survey. The method of data analysis was Qualitative Analysis method where a Narrative Analysis was used to analyze data from online survey and semi-structured interviews and analysis carried out on how incident reporting can reduce risk and prevent accident. Emphasis is on the need for behavioral change and development of safety culture of unsafe act and unsafe condition reporting as a strategy to prevent accident occurrence was analyzed. This research succeeded in developing a template and a framework for incident reporting that can be adopted in any deep offshore oil and gas projects and operations, especially in FPSO operations, to enhance risk management, accident prevention, enhance operational sustainability and business profitability
Predicting the Hydrogen Storage Potential of Ionic Liquids Using the Data Analytics Techniques
Authors: Sulaimon Aliyu Adebayo , Azman Luqman Adam , Zohair Syed Ali Qasim , Adeyemi Bamikole Joshua , Shariff Azmi B , Yahya Wan Zaireen Nisa
Published: July 2023

In recent years, hydrogen has been an attractive substitute as an energy carrier to fossil fuels, though it is difficult to store by conventional means. Ionic Liquids (ILs) are low-melting salts with varying properties of interest. Experimental investigations into the utilization of ILs as hydrogen storage mediums are still ongoing. This study aimed to predict the solubility of hydrogen in ILs using the data analytics method, whereby the correlations between the ILs’ requisite hydrogen properties and hydrogen solubility were developed and validated. The methodology involves comparing the experimental data from the literature and the simulated data from COSMO-RS software, where predictive correlations were developed using analytical software such as Python. The predictive model can be used to predict the hydrogen solubility of ILs based on the input inherent thermophysical properties of the IL before a particular IL is synthesized and tested in an actual laboratory setting.