bluuebunny/crossref_metadata_2025_split huggingface dataset:
Operationalizing Standardized IOGP Start Work Checks by Frontline Workers Using a Digital Solution
Authors: Odiase Kevin , Chukwujindu Kingsley , Onyeoziri Chijioke , Ilechukwu Izundu 
Published: August 2024

Abstract
The Goal Zero ambition of most organizations target no harm, no breaches and no leaks across all her operations. Ensuring this goal remains an utmost priority requires that we keep innovating and adapting new ways of working to ensure positive progress towards this goal. Digital technology has created a robust platform and is redefining how safety protocols are managed across our worksites. Understanding that errors occur, and that most of these errors result from human behaviors driven by the systems and processes is key to delivering the goal zero aspiration.
This paper is aimed at providing an overview of the application of digital technology during Start Work Checks (SWC) at the worksites. The digital SWC solution was designed to narrow the existing site risk ownership and management oversight gaps experienced on the frontline as workers carry out their daily activities. This paper focuses on the development, deployment and embedment of a digital solution intended to address the unique challenge faced by frontline workers, with a significant improvement in risk ownership, real-time data analysis, full implementation of IOGP SWC requirements, whilst removing the use of paper. This tool has positively enabled frontline workers demonstrably prevent incidents and save lives through robust verification of controls prior to start of work. The intervention culture has also improved, in addition to better quality of risk reviews by the frontline folks.
A Novel Approach in Securing Wells Using Nippleless Plugs and Slickline Deployed Memory Tools Saving Rig / Rigless Cost and Time
Authors: Kuro D-J. O. , Akudolu N. , Orumwese S. , Onyeahialam I. C. , Ajentumobi M. , Enifo W. 
Published: August 2024

Abstract
The paramount concerns for stakeholders in the upstream sector of the oil and gas business encompass safeguarding the well-being of individuals and the environment and optimizing revenue through efficient rig utilization. Producing organizations are challenged to make judgments about selecting technological solutions that ensure safe entry and exit from the wellbore. These decisions are crucial in reaching intended targets, ensuring integrity, or securing projects. The ultimate goal is to guarantee the long-term objectives and advantages of the asset. Enhanced technologies and methodologies have been implemented to optimize operational efficiency and profitability while prioritizing safety and meeting delivery expectations. This study aimed to provide a technique for enhancing efficiency in allocating resources for well isolation operations. This involves utilizing Nippleless plugs and memory-operated perforating or activation tools deployed by implementing rigless slickline technology. The methodology above, which utilizes solutions-based tools and technology, was recently implemented during a comprehensive security operation that encompassed two wells located within a field in Nigeria. Suppose the project was implemented using conventional electric line units, necessitating the laborious mobilization of both slickline and e-line equipment. Rig Cost estimate of $100,000 or $10,000 per day with 1Month or 5 to 10 days job execution. This resulted in an estimated project completion timeframe of around ten days. The project was accomplished within fewer than seven days in the both (2) wells, against the duration of the expected project completion period, with a total job cost estimate of $200,000 and $300,000 respectively, with minimal exposure to equipment and personnel on site, resulting in an increase of about 100bbls of oil and providing a business impact of over $10M saved.
Subsurface Safety Valve Control Line Leak Resolution Using a Pressure Activated Sealant Technology
Authors: Robinson Tryphosa , Lucky Ishomo , Iheanyi Ugwa , Chinedu Igwebike , Kenny Mcallister 
Published: August 2024

Abstract
The integrity of critical barriers deteriorates over the life of a well. To support continuous oil and gas production, identified integrity issue needs to be properly managed and addressed.
Most integrity issues are associated with leaks around downhole completion equipment where the tubing retrievable surface controlled sub-surface safety valve (TR-SCSSV) is a critical component. The TR-SCSSV function is achieved by applying hydraulic fluid pressure through a control line (CL) to open it, or bleeding same fluid to close the valve. From the foregoing, the potential for leaks exists around CL termination or connection points, tubing hanger body and/or neck seals and SCSSV hydraulic system seals. When this occurs, the SCSSV integrity is compromised resulting in failure to open the SCSSV flapper. Such SCSSV failure is usually restored with the conventional method of a rig workover to pull and replace tubing with a new SCSSV at a considerable cost.
This paper discusses an in-situ, safe and cost-effective solution, leveraging the pressure-activated sealant technology workflow that was developed and successfully applied to candidate wells with SCSSV CL leaks. It outlines the capabilities of the Seal-Tite technology and the cost-saving production restorations achieved during a campaign in some Mobil Producing Nigeria (MPN) field locations. The overall objective was to diagnose and seal CL leaks to restore integrity, without clogging the hydraulic system or flow path to the safety valve.
Unlocking an Idle Potential Equivalent to a New Gas Well - A Noteworthy Success Story of the Marina-T Well
Authors: Horsfall Ipalibo , Onyeukwu Ifeanyi , Chuka-Umeh Obiageli , Nwokolo Ndubuisi , Obisesan Wale , Anikoh Sam , Ogu Nelson , Kanu Aime , Badmus Olalekan 
Published: August 2024

Abstract
The pursuit of untapped potential within idle wells is a critical focus in the energy industry, offering a significant opportunity to enhance production capacity. This paper presents the comprehensive examination and successful reactivation of Marina-T, a closed-in well within our portfolio. Rigorous analysis, including the review of historical data and multidisciplinary modeling, identified reservoir re-pressurization and cone recession, revealing the potential to unlock approximately 25 MMScf/d of additional resource volume.
Realizing this potential required innovative engineering solutions and collaboration across multiple teams, given the well's secured status, harvested flowline, and fully utilized manifold. By extending an existing gas manifold using equipment from another mothballed gas plant, the well was successfully brought on stream in February 2023, achieving a gas production rate of 30 MMScf/d and a condensate rate of 200 bcpd without any HSE incidents. This reactivation has significantly bolstered the asset's gas production capacity and underscored the hidden value within dormant wells.
The Marina-T reactivation exemplifies the successful implementation of extensive strategies, including intensified data collection, meticulous monitoring, and thorough reviews. This case study highlights the critical importance of data-driven decision-making, effective model evaluation, and cross-functional collaboration in asset revitalization.
Our findings demonstrate the substantial benefits of leveraging untapped potential within existing assets, reinforcing the importance of ongoing innovation and teamwork in the energy sector. The lessons learned from this project offer valuable insights into the processes and methodologies that can drive similar successes in future well reactivations.
Maximization of Value from Brown Assets Through Integrated Short Term Oil Generation
Authors: Nwoke L. , Eta E. , Okoro C. , Ugbojiaku C. , Ndukwe A. 
Published: August 2024

Abstract
The Oil Minning Lease, OML-X (made of several fields), initially operated by a major international oil company with some of its fields discovered in 1963, has experienced significant production decline from its peak in 1967 of 115 Mbopd (and 120 MMscf/d) to less than 30 Mbopd (and 100 MMscf/d) by 2021. This decline was attributed to several factors. The current operator inherited an aging asset characterized by declining reservoir pressures and underutilized gas lift systems. This paper details a comprehensive Redevelopment Strategy implemented by the current operator to reverse this trend and maximize asset value. The approach focused on enhancing production from existing wells and adopting long-term reservoir management best practices. Key interventions included rigless reactivation of shut-in strings, flow line repairs / sectional replacement, and systems integrity assurance, followed by more complex operations. The implementation of this strategy led to remarkable results: a production increase of 78%. This was achieved with a 300% reduced investment and within 50% of the anticipated time, all without any Lost Time Injuries (LTIs). Also, the project saw significant asset integrity improvements through wellhead maintenance and refurbishment. This success story provides valuable insights into the effective management of brownfield assets, highlighting the importance of candidate selection, a SCRUM (agile working system) delivery structure, regulatory collaboration, and integrated teamwork. The approach demonstrated a significant impact on the specific company’s production, with a simple economic indicator of a 5-day payout. Extrapolating these results, the paper concludes that similar strategies could revitalize aging Nigerian oil assets, potentially leading to significant production increases. The case history contributes novel insights to the petroleum industry by showcasing a cost-effective, efficient approach to maximizing brownfield asset value, which could be pivotal for the revitalization of aging oil fields not only in Nigeria but also in similar global contexts.
Re-Entry Considerations to Achieve Production from Suspended Discovery Wells in Offshore Marginal Fields, Niger Delta
Authors: Ade-Fosudo O. O. J. 
Published: August 2024

Abstract
In a bid to increase the crude oil and gas production output from the Niger-Delta and encourage the participation of independent producers in hydrocarbon production, the Nigerian government conducted the 2020 marginal field bid round, in which 57 marginal fields were put on offer for acquisition. 29 of the 57 fields, 51%, are situated offshore, all of which have at least one exploratory or discovery well traversing hydrocarbon sands; whereas most of which are suspended subsea with a wet suspension/trash cap in open waters.
To honor marginal economics and accelerate the field commercialization, some of these suspended wells become relevant for potential re-entry operations to attain first oil; as such, the thought-process for re-entering these aged wells is a critical factor for success. This paper attempts to discuss the key considerations to safely access and exploit these existing wells; including, a subsea inspection to confirm the health state of the subsea cap and its connection, a bathymetric and geotechnical survey, the application of casing risers and/or subsea tieback systems, the role of production loads on the casing, and the acquisition and analysis of the cased-hole logs to verify the integrity condition of the casing. This paper also attempts to bridge the knowledge gap for new independent operators who now own or operate offshore marginal fields, with insufficient experience in upstream offshore activities.
Sand Management Practices at a Mature Field in the Deepwater Niger Delta
Authors: Burgess Matthew , Etoh Emmanuel , Zaki Karim , Oduware Dami , Oyewole Tony 
Published: August 2024

Abstract
Field X is a field in the Niger Delta, located at a water depth of 4,800 ft. The field development strategy includes peripheral water injection and crestal gas injection with mid-flank oil production from multiple stacked reservoirs. All of the wells (injectors and producers) are subsea wells, tied back to a Floating, Production, Storage, and Offloading (FPSO) vessel via subsea flowlines. The production wells were completed with Frac-Packs for sand control and Intelligent Well Completion (IWC) systems to provide zonal information and control for effective simultaneous production of multiple zones per well.
Several years after the start of production at Field X, failure of the Frac-pack sand control equipment were observed on several wells, resulting in sand production. This change in operating conditions was of significant concern because the Basis of Design (BOD) for the field hinged on sand-free production. Sand production could negatively impact the asset integrity of the field by increasing erosion on subsurface, subsea, and topsides equipment, causing damage to topsides production and water injection equipment, and causing process upsets from sand build-up in process vessels.
In response to this new condition, a cross-functional team was assembled to review the root causes of the sand control failure, recommend operational changes to prevent future sand control failures, recommend options to mitigate the impacts of sand production to the field infrastructure and process systems, recommend strategies for performing surveillance of equipment to assure asset integrity, and maximize the value of the asset within the context of the new paradigm created by the failed sand control. This paper will highlight the strategies and methodologies adopted to manage sand production at Field X, which include maintaining production from wells with failed sand control at curtailed rates to achieve sand free production, preventing additional completion failures through enhanced flux modeling and by proactively performing acid stimulations to reduce velocities and erosion through the completions and help preserve completion integrity, and maintaining subsea and surface facilities integrity and operability through increased surveillance and solids management programs. These mitigation measures have helped to maintain production and minimize negative impacts to field EUR while maintaining asset integrity and operability.
Navigating the Depths: Mitigating Operational Challenges in Offshore Well Drilling through Efficient Logistics Management
Authors: Igbeka Uche , Sakpa Ogaga , Ojubanire Damilola , Okoli Ugo’ , Okwa Hope 
Published: August 2024

Abstract
Offshore well drilling is a complex and high-CAPEX operation that demands meticulous planning and execution. This abstract delves into the critical aspect of logistics in offshore drilling, highlighting the paramount importance of effective management to avoid costly pitfalls and ensure the success of drilling projects.
The offshore drilling landscape is fraught with challenges, ranging from extreme environmental conditions to the intricacies of geological formations. However, one often underestimated yet crucial factor influencing project outcomes is the impact of logistics on operational efficiency. In the realm of offshore drilling, where remoteness and harsh conditions prevail, the ability to seamlessly coordinate and manage logistics becomes a linchpin for success.
This study focuses on ‘How not to drill a well’ by shedding light on the potential pitfalls associated with poor logistics management. Inefficient logistics can manifest in various forms, from delayed shipments of essential equipment to late or poor mobilization of personnel, and suboptimal supply chain coordination. Such issues can result in costly downtime, project delays, and compromise overall safety standards.
The paper draws on a real-world case study to illustrate instances where inadequate logistics planning has led to operational setbacks. It underscores the domino effect that logistical challenges can trigger, impacting drilling schedules, budget adherence, and even the environmental sustainability of the operation. By dissecting this case study, the research aims to provide valuable insights into the specific areas where improvements in logistics can significantly enhance overall project outcomes.
In conclusion, this abstract encapsulates the critical role that logistics plays in the success of offshore well drilling projects. By understanding ‘how not to drill a well,’ industry stakeholders can proactively implement strategies and technologies to fortify their logistical frameworks, ensuring smoother operations, minimized risks, and enhanced overall project success.
Deepwater Nigeria Integrated Activity Planning (IAP): A Key Lever to Competitive Optimization and Consistent Business Performance
Authors: Ogbunude Basil , Adeleye Olabode , Edache Ako , Wali Asmau , Ochonogor Chukky , Ezugwu Chima , Ashafa Dipo 
Published: August 2024

Abstract
While a robust business plan forms the bedrock for setting the goals and aspirations of the SNEPCo Deepwater (DW) portfolio over a long-term time horizon, the purpose of the Integrated Activity Planning & Scheduling (IAPS) process is to integrate, prioritize, optimize, and check readiness of activities to be carried out by functions on the DW asset as prescribed in the business plan to enable effective and efficient execution of work. These activities impact safety, production, capacity, cost, and simultaneous operations and rely on the IAPS process as the major driver for an integrated delivery. The plan outputs include deliverables such as Supply Chain demand profiles, Asset wide integrated Turnaround plans, activity readiness, scenarios and the impact of various threats and opportunities. The plan sets out the asset and functions’ Programme of work together with the activity timings, i.e. execution windows directly supporting their business targets, business plan submission and latest estimates of cost and production.
The objective of the DW IAPS is to maximize business value and mitigate risks to the asset by delivering: Goal Zero (Personal and Process Safety) by planning conflicting activities at different times to minimize exposure to personal and process safety events.Top quartile availability by integrating activities that cause deferment and reduce facility downtime.Cost competitiveness by optimizing the use of critical resources.Environmental Stewardship / Regulatory Compliance.
Since IAPS was introduced in SNEPCo 10 years ago, the asset has undertaken a bespoke efficiency improvement journey in delivering real value to the DW asset, ensuring a consistent top-quartile performance in key safety, production and activity-driven metrics year-on-year. Leveraging the integrating role of the IAPS workstream, several performance enhancing and IT-enabled simplification initiatives have been adopted over the years to ensure a competitive outcome for the asset as prescribed in the business plan. This paper summarizes the strategies, concepts and systems developed and deployed over the years to deliver a robust IAPS process that effectively supports integrated management of SNEPCO’s deepwater activities. The paper will highlight the challenges, opportunities, and improvement scopes for the IAPS process as well as learnings derived from a decade of IAPS operations in the SNEPCo Deepwater business.
Managing Complex Challenges in Reservoir Redevelopment: Case Study of X-Sand in the Niger Delta
Authors: Kumapayi O. Y. , Orupabo S. , Chinonyerem C. , Ishola A. P. , Olatoke O. , Fawumi O. , Onyido C. P. 
Published: August 2024

Abstract
As a field matures with time, it becomes pivotal to leverage on historical production and subsurface understandings to identify further development opportunities. However, there are challenges such as drilling through depleted sands and infill well placement optimization that could impact the success of reservoir redevelopment.
The objective of this study was to propose an optimized redevelopment plan via a detailed cross functional subsurface evaluation of a matured reservoir with considerable historical data coverage laden with some challenges such as current contacts, connectivity uncertainty and depleted sands. To achieve the objective, a structured subsurface workflow was utilized to assess the execution feasibility, recovery and challenges associated with the opportunity development.
A reservoir simulation model was built, history matched for recovery assessment; Historical contact data tracking was conducted in the simulation model that helped define current contacts and infill wells placement; Subsurface reservoir scenario modelling was conducted to characterized different potential dynamic scenarios in the reservoir. An integrated pore pressure prediction and wellbore drilling evaluation was conducted to identify strategies and manage drilling through depleted sands leveraging technology. Sensitivity runs were carried out to identify optimum production rates and well lateral lengths as well as economic analysis.
Study outcomes suggest a proposal of 2 wells (3 completions) to optimally deplete the reservoir of interest in the long term. A detailed Managed Pressure Drilling (MPD) plan was planned and recommended for identified shallow depleted reservoirs during well execution. Study results show robust economics and significant return on investment.
Investigating the Effectiveness of Gas Re-Cycling for Improved Condensate Recovery in Gas Condensate Reservoirs: A Field Case Study
Authors: Adesola Tunde , Olajuwon Nicholas , Ibe Alonge , Udoh Nsikak , Olafuyi Olalekan. 
Published: August 2024

Abstract
The productivity of a condensate reservoir in the Niger-delta region of Nigeria is declining. The initial production rates for oil and gas were reported to be 350 barrels per day and 1.2 million standard cubic feet per day, respectively. This poses a unique difficulty for reservoir operators in determining the most effective way to optimize recovery. In this study, we use the CMG reservoir simulator to analyze the effects of gas recycling on the recovery of condensate and gas in a typical gas-condensate reservoir. The aim of our study is to assess the effectiveness of gas recycling in improving the overall recovery of hydrocarbons while keeping the pressure in the reservoir stable. We employed the gas recycling approach by employing the same well for injection, instead of drilling a new well, and compared its performance to a baseline scenario without gas recycling. The findings demonstrate that the process of gas recycling has a substantial positive impact on the rates of condensate and gas recovery. In comparison to the baseline scenario, our gas injection resulted in a significant increase in condensate recovery, around 100 barrels per day, which accounted for the whole amount of condensate being produced at that time. In a similar manner, the gas recovery increased by about 1 million cubic feet per day, reaching a level where it accounted for more than 70% of the gas being generated. The gas injection pattern showed enhancements, however it necessitated greater injection rates due to the failure to achieve early recovery levels. Finally, the well's downhole pressure was greatly boosted, although this did not result in the best possible recovery performance. This study indicates that gas recycling shows great potential for improving the extraction of hydrocarbons in gas-condensate reservoirs. By utilizing sophisticated reservoir simulation models such as CMG, we can enhance our ability to forecast the results of different gas recycling schemes and steer decision-making towards more sustainable and economically feasible development strategies.