bluuebunny/crossref_metadata_2025_split huggingface dataset:
Practical Hydrocarbon Allocation – A Machine Learning Approach
Authors: Diaso K. I , Kalio J. , Owoseni S. M. , Duruzor E. , Onasanya B. 
Published: July 2023

Abstract
The current conventional method of hydrocarbon production allocation of reservoir fluids’ contribution to the separate producing strings from commingled production in the oil and gas industry considers some rigid assumptions that make the allocated volume mostly unreasonable. This uncertainty is usually due to the fixed decline rate assumption normally adopted for a specified period until a new well test of the contributing strings is available to generate a new allocation factor anytime production allocation is required.
This paper presents an artificial intelligence approach in the determination of real-time allocation factors for determining contributing production flow performance from commingled production using a machine learning algorithm with the fixed rate assumption using well flow parameters such as the flowing tubing head pressure, flowline pressure and other well parameters to generate transient rates for the producing strings, to create new allocation factor when required.
Data from marginal fields in the Niger Delta were used as case studies and the results generated from this exercise after proper data pre-processing depict reasonable output with precision of high confidence level. Results from this approach can also be used in the absence of a reliable well test.
Achieving Sustainable Energy Transition; - What Works in Sub-Saharan Africa
Authors: Kelechi F. M. , Ogbodo I. S. , Adah J. A. , Aribisala A. A. , Akagbosu P. I. 
Published: July 2023

Abstract
According to a United Nations report from November, 2022, the world population reached 8 billion for the first time in human history with 6.74 billion people living in low and middle - income countries (LMICs) and 1.3 billion living in developed countries. 53 of Africa's 54 countries fall under the former category. The population of Africa is estimated to be 1.4 billion with 1.17 billion in sub-Saharan Africa. Presently, 770 million people globally have no access to electricity mostly in Africa and Asia with 3.8 billion depending on solid fuels for cooking and other domestic uses. Data obtained from WHO reported that 568 million people in sub-Saharan Africa are living without access to electricity and clean energy. In developing nations, wood, charcoal, and dung are commonly used as traditional cooking fuels, with wood being the primary source of energy. The emission from these fuels in addition to those from fossil fuels further reduces the quality of air which causes ambient air pollution, a condition with adverse effects on human health. However, there are initiatives that have been adopted to alleviate the problems including the future expectation for global access to clean energy as conveyed in the 2030 United Nations Sustainable Development Goals (goal number 7); the 2063 African Union Commission Agenda; the Paris Agreement at COP21; and the United Nations Sustainable Energy for All (SE4A). This paper reviews historical trends in energy usage in sub-Saharan Africa, the present conditions and status of development, across policy and technological prongs, in terms of the current energy transition. Furthermore, the paper seeks to highlight opportunities for future sustainable energy development across all sectors and businesses in order to provide energy to the 568 million without access in sub-Saharan Africa, while bearing in mind the environmental implications for the global population at large.
Rigless Conductor Piling Using Threaded Tubulars - A Strategy to Sustain Oil Production in Onshore Niger Delta
Authors: Mrakpor O. , Adigolo C. , Anorue F. , Udi E. , Oga-Eluwa K. , Ahaneku G. , Campbell W. 
Published: July 2023

Abstract
Onshore Producing wells in proximity to new cellar slots are required to be shut-in during rigless conductor piling operations using welded conductors. The project objective is to design a novel technology system that can safely makeup and drive threaded conductors without using a drilling rig, thus preventing welding operations (hot works) and production deferment.
A multi-disciplinary approach of drilling, safety and structural engineering was implemented during the planning phase. System integration test (SIT) was carried out between the drive sub, piling hammer and conductor. Anticollision analysis was carried out to prevent collision issues with producing wells. Conductor pipe specification was defined to withstand piling loads. A two-staged support frame was designed and fabricated for conductor centralization. Conventional tubular running equipment was combined with piling equipment to make-up and drive threaded conductor pipes. Conductor verticality was achieved using two cranes positioned perpendicularly, working in-tandem and personnel coordinated with intrinsically safe radio devices.
The use of this hybrid technology ensured that three slots were successfully piled without welding operations or shutting-in producing oil wells, saving a total of 21,000 bbls ($1.89m @ $90/bbl). Case studies of previous rigless conventional piling operations using welded conductors were compared with the slots piled using the novel rigless hybrid technology. The new approach is safer and more efficient with utmost benefits in sustaining hydrocarbon production in existing locations with live wells close to the new slots. The most significant new finding is that it was possible to make up and drive threaded conductors safely onshore without using a drilling rig, thereby eliminating welding (hot) works.
Zeolitic Imidazole Frameworks for Super Selective Separation of Propylene from Propane
Authors: Agbajei T. A. , Karanikolos Georgios N. , Khaleel Maryam 
Published: July 2023

Abstract
Olefin and paraffin gases are important products of the petrochemical refining industry wherein their effective separation could provide high economic gains and competitiveness in the emerging energy markets amidst state-of-the-art technology. Important chemicals such as polyethylene and polypropylene are derived from raw materials in the form of light olefins, including ethylene and propylene, processible via naphtha cracking. However, since this leads to its production among other valuable by-products separation/refinement is required and this is commonly achieved through technical and energy-intensive cryogenic distillation due to the similarity in thermophysical properties of the process effluents. Thus, cost-effective and energy-efficient processes are required among which membrane-based separation techniques stand out. In that line, zeolitic imidazolium frameworks (ZIFs) have shown a superior potential to provide high selectivity and high permeability to particular species in a mixture they are used to refine. This superior effectiveness is attributed to ZIF's uniform pore sizes that enable sharp molecular sieving, as well as its highly porous structure that enables fast species transport through it, with minimal mass transfer hindrance for the targeted/preferably selected specie. Among ZIFs, there exists one called ZIF-8 which is especially suited to propylene/propane separation and has been widely reported for its sharp molecular sieving performance for this mixture. ZIF-8 is also distinctly stable, and relatively easy to synthesize from cheap and readily available starting materials. Recent advances in the fabrication methods reported for ZIF-8 synthesis are presented in this work, along with a comparison of the separation performance for propylene and propane resulting from different types of ZIF-8 produced by these methods. The potential effect of utilizing this ZIF material in the refining units applied for olefin/paraffin separation is also critically evaluated towards its industrial utilization.
Accessing Energy Resources in a Complex Geologic Setting Unraveled by Ocean Bottom Node (OBN) Seismic During Project Execution
Authors: Ochai-Audu E. N. , Otung A. D. , Mora-Glukstad M. , Nworie E. 
Published: July 2023

Abstract
As we go through the energy transition, accessing energy resources in a complex geologic setting such as the shallow offshore Niger Delta remains a challenge. Utilizing advanced technology/method to understand the subsurface and locate the remaining "advantaged hydrocarbon" is key for optimal well placement and sustainable production. The unsuccessful drilling results of a recent late life Shallow Water Asset development campaign drove the use of recently acquired advanced technology seismic, Ocean Bottom Node (OBN) integrated with other data set to analyse the reason for the well failures and propose alternative scenarios. As the resulting evaluation clearly explained why the wells failed, technical reviewers considered that the results were sound and supported the drilling of a new well based on the latest evaluation. A new well was successfully drilled, reservoir parameters matched new predictions and initial production was estimated at ~2000 bblo/day. Results showed that the structure is much smaller than what was initially interpreted on the legacy seismic. Hence, plans to drill more wells into the structure was dropped. The learnings from this evaluation were deployed to all planned shallow water wells to prevent future suboptimal well results.
Integrated Approach to Addressing Well Integrity Challenges: A case study of Well AA
Authors: Ezenobi Eric , Alli-Oluwafuyi Jumah , Imorame Imonitie , Okolomma Emmanuel , Biambo Tamunotonye , Laoye Abiodun , Ayodele Bunmi , Nworie Ejiuwa 
Published: July 2023

Abstract
Operating wells safely is a critical aspect of E&P business because of the significant exposure and huge negative impact of associated incidents on People, Asset, Community and Environment. Well integrity failure has grave reputational and financial consequences which can ultimately lead to losing license to operate and/or loss of lives. In our company, well integrity management receives topmost leadership focus, with requisite standard guidelines, which are regularly reviewed and updated to ensure the objective of operating wells safely are achieved.
The risk of loss of well integrity is higher as wells age, however, in some very few cases newly completed wells may also fail. Loss of well integrity could result in sustained annular pressure, hydrocarbon spill, underground blow-out, or contamination of ground water aquifer in some cases. The potential causes include (but not limited to) poor cement annular cementation or bonding, casing/tubing corrosion and/or compromised completion jewelries.
Our case study, Well AA is situated in the shallow offshore terrain of the Niger Delta. The well was completed as a Single String Single (SSS) horizontal oil producer. Shortly after the well came on-stream, sustained high A-annulus pressure was observed during ramp-up. This eventually exceeded the Maximum Allowable Annular Surface Pressure (MAASP), resulting in a well integrity concern.
A comprehensive risk assessment was carried out to identify potential leak path, generate risk assessment matrix and recommend preliminary leak investigation activities. In line with the guideline, initial bleed-down procedures were deployed but this did not abate the A-annulus pressure. Detailed downhole investigation integrating spectral noise and high precision temperature logs confirmed the production packer was compromised. Subsequently, well AA was worked over and integrity restored, safeguarding production promise of over 1500 bopd.
This paper therefore details the integrated approach taken by the asset team to identify the well integrity issue, assess risk level, investigate cause of A-annular pressure build up and how it was addressed. This paper is intended to provide a guide to technical staff facing similar well integrity challenge.
Reservoir Modelling of Multizone Completions in Brown Field Excellence Workover Wells
Authors: Ikwan Ukauku , Azugwu Isidore , Iwegbu Chibuzo , Avu Albert , Agwu Ndukwe , Eta Edirhin 
Published: July 2023

Abstract
Many fields in the Niger Delta are made up of stacked reservoirs. Conventional completion and production are by bottoms-up approach. Multizone completion using one string as a key element of Brown Field Excellence is novel or at best evolving in Nigeria. It ensures many reservoir intervals are completed and comingled during production and has many benefits. Major challenges are delivery schedule of equipment, additional regulatory approvals and cross flow that could impact both rate and ultimate recovery. Proactive engagements for co-creating the solution at design phase is a panacea for successful multizone completion workover. In this paper, a muti-tank material balance reservoir model was built and used to predict performance and cross flow phenomenon in eight comingled stacked reservoirs. Most importantly, the model shows that in this novel approach of WO recompletion it is possible to achieve an instantaneous potential of 11.5 Kbopd with 8 zones comingled even in the presence of cross flow from an old well that made a maximum of 3.0 Kbopd from conventional completion. By closing the cross flow big heater reservoir from the onset behind sleeve till cross flow ceases following pressure equilibration, it is even possible to achieve initial instantaneous potential of 12.0 Kbopd. It is recommended to use the model to close behind sleeve, interval with negative flow rate (cross flow) during production of the multi zone completed well. The modelling approach in this paper is recommended for application in other Brown Field Excellence multi zone completions in any multizone workover portfolio. The model could also argument hydrocarbon accounting techniques of routine finger printing and production logging since it predicts contributions of all fluids from each zone viz oil, gas, and water rates as a function of time.
Exploring the Feasibility of Implementing Polyalphaolefin (PAO) Lubricants as an Alternative Lubrication Solution in the Petroleum Industry
Authors: Akpoghomeh O. 
Published: July 2023

Abstract
The petroleum industry is a significant consumer of lubricants, with an estimated consumption of more than 2 billion gallons per year. However, the use of traditional lubricants in this industry can have significant environmental and economic impacts. One potential alternative lubrication solution is the use of Polyalphaolefin (PAO) lubricants. PAOs are synthetic hydrocarbons that are biodegradable and non-toxic and can provide good lubrication and corrosion protection.
This research aims to investigate the feasibility of implementing PAO lubricants as an alternative lubrication solution in the petroleum industry. The study will include a review of the current state of the art in PAO lubricants and their potential application in the petroleum industry. The study will also include laboratory testing to evaluate the performance characteristics of PAO lubricants in comparison to traditional lubricants under various conditions representative of the petroleum industry.
This research will provide a comprehensive analysis of the technical, economic, and environmental aspects of using PAO lubricants in the petroleum industry. This includes the evaluation of the costs and benefits of using PAO lubricants, as well as the environmental impacts associated with their production and use. The results of this research will provide valuable information for the petroleum industry and could potentially lead to a significant reduction in the environmental impact of lubricants used in the petroleum industry.
It is expected that this research will show that the use of PAO lubricants could lead to a reduction of up to 15% in lubricant consumption and up to 20% in greenhouse gas emissions in the petroleum industry. Additionally, it's estimated that the use of PAO lubricants could lead to a significant reduction in the environmental impact of lubricants used in the petroleum industry, with a reduction in the environmental impact of up to 50% compared to traditional lubricants.
In-House Software Development for Viscosity Computation
Authors: Lukpata J. L. , Mmata B. , Onyekonwu M. O. 
Published: July 2023

Abstract
Viscosity is one of the most important fluid properties required in characterizing or evaluating hydrocarbon oils. Experimental measurement of viscosity can be strenuous and time consuming especially for dead oils; even when measuring with top notch equipment models like Vinci 1000 viscometer, Amatek CAP1000+ viscometer, etc. Amongst the various viscometers available in the petroleum industry, the cannon-fenske viscometer is a widely used and accepted model for dead oil viscosity measurements as it conforms to ASTM 445. Although very self-efficient, the use of this equipment involves time-consuming computations. A more challenging task with this equipment is choosing a suitable tube size for a particular fluid. This involves a long series of trials and validity checks which invariably leads to man-hour loss. This work introduces a user-friendly software solution for use with the cannon-fenske viscometer. The software was built on the python Graphical User Interface (GUI) framework, Tkinter, employing modules as Pandas, NumPy, Sklearn (scikit), etc. It was developed within the JetBrains PyCharm 2022 Integrated Development Environment (IDE). Object-Oriented Programming (OOP) technique was adopted for implementing the workflow for all calculations. This software solution performs all calculations and checks associated with the cannon-fenske viscometer. In addition, it comes with a built-in stopwatch that can be used in the absence of an external stopwatch. Validation of results was done using fifty-five (55) data sets from the laboratory. It is concluded that the use of the software reduces human errors associated with manual computation of results while using the cannon-fenske viscometer. The use of this software also makes viscometer tube selection easy. The overall time spent on viscosity measurements is reduced (by more than 50%) with the use of this software.
Well Diagnostic of New Underperforming Wells Using Downhole Log Tool [SNT & MDT]
Authors: Gidado A. O. , Ekesiobi C. , Kpone-Tonwe H. , Adesun J. 
Published: July 2023

Abstract
Production of hydrocarbon from wells drilled into oil bearing zones for sustained period of time could result in wellbore integrity damage, which is capable of shutting down oil and gas production. To detect such problems, a diagnostic operation is performed to acquire and identify the source(s) of the wellbore integrity damage. The result of this, is raw subsurface well data, requiring further qualitative interpretation to establish causes and solutions to wellbore problems. To improve the accuracy of subsurface well data qualitative interpretation, the data acquiring process must be efficient and painstakingly performed. This work outlines and describes process of acquiring data through well diagnostics. This technique is applied to a well in the Niger Delta area operational for 10 years. The production volume from the well was about 68% lesser than expected rate from the DST result. Magnetic Thickness detection (MTD) and SNT-Temperature log were deployed as a wellbore diagnostic tool. The MTD tool run in the long string of the well from 13,742ft to 10,302ft, helps in detecting End of Tubing of the short string at 10,562.6ft, corrosion detection (Tubing Wall loss) at 12% maximum, perforation depth and casing conditions. The SNT-Temperature tool was run through the entire length of the tubing. It helped in detecting tubing leak at 13,391ft, formation activity between two reservoirs at 13,530ft – 13,560ft and fluid flow from perforation depth. These diagnostic analysis helps in identifying uncertainties in the well bore, thereby postulating direct solutions for the well.
Implementation of Engineered Rigless Through Tubing Sand Exclusion Solution to Enhance Hydrocarbon Production: The Field X Case Study, Niger Delta, Nigeria
Authors: Momodu Ehigie , Soro Augustine , Olaoye Abiodun , Omedo Augustine , Osode Peter , Olugbade Oluwatobi Raymond , Akinlade Deji 
Published: July 2023

Abstract
Sand production is widely recognized to have a detrimental influence on well deliverability and creates safety concerns because of equipment damage and surface flowline breaches. Sand production, while unavoidable in highly permeable reservoirs like in the Niger Delta basins, is deleterious to both downhole completion and surface hydrocarbon production and treatment systems, as with the candidate wells in the Field X. Sanding in these candidate wells required sand management being a daily routine alongside daily hydrocarbon production throughout the life of the wells until it became unmanageable and costlier, resulting in most of the wells being shut in, thus causing significant production deferment and loss of revenue
An immediate need for a safe, cost-effective, and timely Sand Exclusion Solution was required to improve and restore production with minimum allowable/manageable sand production from the wells. To find the optimum approach to address the sand production issues, a variety of alternatives were considered, including well recompletion workover, in-situ sand consolidation, internal gravel packing, and rigless Thru-Tubing Sand Screen Hang Off, to restore completion integrity. Following several review meetings, Thru-Tubing Sand Screen Hang-off was chosen as the safest, time and cost-effective choice because of its minimal equipment spread, properly sized sand screens and in-house knowledge to for successful installation. However, intervening the candidate wells with minimal equipment spread required thorough subsurface studies, well engineering, and reservoir simulations (Nodal Analysis), to tailor the solutions to what the wells required.
Phase Behaviour of a Near-Critical Gas Condensate Reservoir Fluid from a Conventional Field in the Niger Delta
Authors: Mmata B. , Kiinee L. , Okeke H. , Onyekonwu M. O. 
Published: July 2023

Abstract
Near-critical gas condensate reservoir fluid like near-critical oil has a very complex hydrocarbon phase behavior and is likely to be encountered as deeper formations are been drilled in an extensive search for hydrocarbon deposits. It is a highly unconventional fluid and lacks adequate characterization approach in the open literature due to its complexity as it is found in the near critical region of a hydrocarbon phase envelope of a multi-component system. All known Equations of State models such as Peng Robinson (PR), Soave-Redlich-Kwong (SRK) etc, have been found to be inadequate in characterizing this fluid. This paper presents an experimental methodology and results of a Pressure-Volume-Temperature (PVT) analysis done on two near-critical gas condensate reservoir fluids from a gas field in the Niger Delta region. Constant Composition Expansion (CCE), single stage flash and reservoir fluid composition analysis were carried out using state-of-the-art visual PVT cell and gas chromatograph. The CCE test performed clearly showed the unusual but unique formation of two liquid phases rather than one liquid phase during the isothermal depressurization below the dew point pressure and the subsequent disappearance of the lower liquid phase. This critical opalescence phase behavior is unique to a near-critical gas condensate fluid. The CCE experiments also showed the maximum liquid drop out (LDO) behavior (about 45% condensate dropout) at a small pressure drop of 100-150 psig below the dew point pressure. The C7+ mole percent (&lt;12.5%) and the produced gas-oil ratio (&gt;5,000 SCF/STB) were other parameters used to further provide a reasonable insight that the fluid under study is a near-critical gas condensate. In conclusion, proper characterization of a near-critical gas condensate reservoir fluid will greatly aid the reservoir and production engineers to have a better and more robust field development strategy to produce and manage near-critical gas condensate reservoir.