bluuebunny/crossref_metadata_2025_split huggingface dataset:
Mero Field: Integrated Development, Challenges and Innovations
Authors: Neder Ana Luiza , Calôba Guilherme Marques , da Silva Letícia Soares , Hayashi Mauro Yuji 
Published: October 2023

Abstract
Mero field is among the biggest hydrocarbon discoveries in Brazilian pre-salt province and turned out to be a giant and high productivity reservoir. However, it has characteristics such as thick and heterogeneous carbonate reservoir, high reservoir pressures, high Gas-Oil Ratio (GOR), high CO2 content and presence of H2S that makes exploration and production challenging, as it requires specialized equipment and advanced technologies.
An important pillar for the field, integrated development, is the Project Based Technology Development. Mero leverages existing or innovative technologies and aims to identify and close technology gaps in an integrated approach to maximize project value and increase its attractiveness.
One of the primary challenges in highly complex reservoir, such as Mero, is deep reservoir understanding, and a robust drainage plan strategy. To mitigate all the main risks that could affect the Project results, Data Acquisition in the Production Phase must be planned and executed to minimize impacts on the Project deployment, obtain the information in time for optimizing the Project, and maximize the production and results at every moment. To maximize oil recovery and obtain a sustainable development, Mero Project considers the reinjection of gas and CO2 through alternating water and gas injection method (WAG) in all injector wells. A variety of offshore technologies were pushed beyond its previous limits, establishing industry "firsts", which have enabled an accelerated approval process and the development of the next production systems.
To overcome all the technical and economic challenges, the Consortium created an integrated cooperative environment. As a result of the big integration between Consortium members and the supply chain companies involved, Mero Project is conceived through the application of several cutting-edge technologies, enabling the recovery of this large reserve with competitive break-even and robust carbon storage in the reservoir. Those practices were key to deploy two early production systems (FPSO Pioneiro de Libra) and one definitive system (FPSO Guanabara) – currently the higher FPSO in production in Brazil. The total field production is around 230.000 bpd and there are three others FPSOs to be deployed in the coming years.
A compiled of practices applied to overcome the Mero field challenges and maximize the project's results. Those practices came from all the technical disciplines, such as Reservoir, Wells, Subsea, FPSO and Operations, as well as Compliance, HSE and management of the Production Sharing Contract. Some Technologies developed include but are not limited to Permanent Reservoir Monitoring (PRM), Cargo Transfer Vessel (CTV) and HISEP®, a Petrobras patented technology specifically designed to deal with high CO2 and gas content in Mero Reservoir.
Standardizing Drilling Fluids Practices has Reduced Stuck Pipe Non-Productive Time During Drilling Through Fractured Dolomite Formation Under Complete Loss Circulation, Case Study in Kuwait
Authors: Soliman A. , Elsayed R. I. , Sayed H. E. , Alarouj B. , Al-Khaldy M. , Khan Y. , Al Bannay M. , Das A. K. , Hamed A. A. 
Published: October 2023

Abstract
In the event of mud complete loss circulation while drilling through fractured Dolomite formation, the economical drilling fluids technique was to continue drilling with lime treated water and pump mud cap in the annuals, although this technique overcomes the need and cost of mixing drilling fluids on fly, but it caused several problems that led to stuck pipe and lose the directional tool / BHA in the hole. The manuscript describes a study performed to analyse the root cause of stuck pipe incident and presents a detailed success case of utilizing customized non-damaging drilling fluids.
While drilling in well BG-1832 located in southeast Kuwait field through fractured Dolomite formation (Shuaiba) a complete lost circulation has been encountered and the decision made to continue drilling with water in inclination of 90 degree. Once total losses occurred the variations between ECD and ESD was very low indicating that annular friction losses below the loss circulation zone was minimal. This support the theory that all the drilled cuttings are properly lifted from bottom and carried to loss circulation zone and not fluctuating above the loss zone. Due to cuttings accumulation and differential pressure it led to stuck pipe and lost the directional tool / BHA in the hole. The well has been side-tracked and non-damaging WBM has been utilized to drill 8 ½″ hole side-track, which improved the holing cleaning and successfully drilled the hole and a achieved the well target successfully as per plan.
The customized non-damaging drilling fluids was designed taking the following objectives in consideration: Enhanced hole-cleaning efficiency at critical anglesMinimized risk of stuck pipe across depleted formations with high porosity and permeabilityMinimal damage to reservoir section during drilling phaseReduced the drilling hours by improving ROP and minimizing the required time for wash up and ream down prior connections.Reduced the required mixing time by 70% comparing to conventional non-damaging Calcium Carbonate water base mud.
This paper presents a real case study of applying a customized drilling fluid to reduce the non-productive time by mitigated the risk of stuck pipe and losing expensive tools in the hole. It confirms the theory of the hole cleaning in total lost circulation, and includes a full drilling fluids analysis, hydraulic engineering study, lab test and performance / economical comparison.
Challenges and Solutions for Asset Integrity Activities on Normally Unattended Offshore Facilities
Authors: Igbadumhe J. F. , Feijo L 
Published: October 2023

Abstract
The future of the oil and gas industry includes zero manning onboard complex facilities such as Floating Production, Storage and Offloading (FPSO) units. Driven by safety concerns, the use of Normally Unattended Facilities (NUF) aims primarily at reducing human exposure to hazards related to offshore operations. The application of NUFs implies that Asset Integrity Management activities including inspection and maintenance would be carried out remotely and/or with limited human intervention. This paper identifies the challenges faced in managing remote integrity management activities of complex NUFs. Aiming at maintaining safe and continuous operations of complex NUF facilities, operators need to mitigate the likely challenges that would affect the remote integrity activities. This paper approaches these activities in a NUF in parts, depending on the characteristics of the asset and the criticality of each element. Quantitative risk assessment method that incorporates the role of age is used to evaluate potential disruption and define mitigation techniques. The role of age is described in four stages: early life, operational life, late life, and end life. Risk Priority Number (RPN) are obtained to judge the effectiveness of the defined mitigation techniques at the four stages of the life cycle. Class Society standards are also an important tool for this evaluation. As a consequence, recommended methodologies are identified to address the NUF integrity management processes. Despite NUFs being designed and operated considering limited occurrence of manned activities based on a pre-determined duration, unforeseen events can distort the daily operations of complex facilities such as FPSOs. In addition, as the NUFs age, the required human intervention is expected to increase due to the natural degradation of the asset. The result of this investigation shows that at the different stages of the life of a NUF, the survey, inspection, and maintenance challenges will present different demands, therefore requiring an adjustment on the methodology and technology applied on the integrity management activities. Several factors contribute to this, including changes in operation profile, failure modes and degradation mechanism. As a result, the intervention program may need to be altered to accommodate such changes, enabling effective remote surveys, inspection, and maintenance.
Development of a New Digital Monitoring and Surveillance Platform in a Regulatory Agency in Latin America
Authors: Zarate G. , Tello Bahamon C. C. , Vivas P. 
Published: October 2023

Abstract
Hydrocarbons regulators and inspectors face technical and operational challenges in monitoring fields and assets. The remoteness of field locations, data governance and contractual rules make this task difficult to track. This paper presents the implementation of a monitoring platform designed by a regulatory agency in Latin America, the underlying technology, the process followed, and the results and benefits of this initiative. This monitoring platform was developed using various systems to support the data streams used in the overall process. During the first phase, the system architecture was defined to outline the main components of the monitoring platform, data flows and hierarchy. A data quality and standardization process were outlined to ensure consistency and validation of the data coming from the oil and gas assets. A production data management system was then integrated to collect, store, and display all production operations information and measurements. In addition, a Geographic Information System was embedded into the monitoring platform after a careful review of geo-referenced details of fields and wells for each of the operating companies. Finally, the user interface design included the definition of monitoring dashboards and various visualization screens.
Female Mentorship in O&G Industry the Pathway to Diversity
Authors: Cipriano K. , Cabral C. R. 
Published: October 2023

Abstract
Energy transition is crucial for the future of the planet, and the Oil & Gas industry is at the center of climate change. Rethinking this industry will require innovative and disruptive solutions. For this to occur, it is necessary to have diversity at all levels. Gender diversity is the starting point of this work, which focuses on female mentoring as a potential solution to achieve more diversity in the O&G industry and, thereby, bring about the changes that the industry and the planet need. In the present study, female mentoring was discussed, and its results were analyzed, as well as the importance of the topic for Petrobras, a leading company in the O&G sector in Brazil. These results can be used to inspire other companies to promote a similar program and to achieve better results in terms of diversity.
Well Control for Formation Test Tool – A Case Study of Kick Circulation After a Formation Test Operation
Authors: Motta M. , Machado P. , Reigoto D. , Lustosa R. , Almeida D. 
Published: October 2023

Abstract
Well control operations in high-pressure/high-temperature (HPHT) environments can be challenging and costly, besides well control incidents can cause, in addition to economic damage to companies, an incalculable impact on the environment. Once a formation test operation is performed, it is possible that after getting the samples from the formation an extra quantity of fluid could invade the bottomhole and cause a well control incident. The main purpose of this paper is to present a successful simulation case of how a small amount of hydrocarbon, when collected after a formation test operation, is managed under a specific scenario. The outcome is achieved by understanding wellbore conditions using an advanced well control simulator, thus abnormalities normally failing in conventional practices can be detected and explained. This improves not only safety and performance, but also allows for an effective application of resources (Davis, Selent, & Duplessis, 2019).
Normally Unattended FPSO Design
Authors: Costa Filho Fernando Homem , Freitas Junior Rivadávia Vieira , Assayag Salomão 
Published: October 2023

Abstract
Considering the last 50 years of offshore activity experience and the evolution of the technology, unattended installation designs started to be proposed for application. The focus is to reduce the O&M cost keeping operational reliability and safety. Although some of the low-complex process platforms have been unattended and operated on for many years, especially for small or marginal fields with OPEX/CAPEX restraints, nowadays, unattended platforms for new oil discoveries requiring more complex installations are being considered. A new approach to design, O&M, and logistics is being adopted to enable more complex processing platforms to operate as unattended installations. The unattended platform will be operated remotely by the operational team onshore, and the maintenance team will be aboard only when required for corrective maintenance or during planned preventive maintenance. Unattended platform design philosophy should prioritize the simplicity and the reduction of systems and equipment on board, focusing on maintainability and keeping high operational efficiency. This paper presents a functional analysis of the usual systems that compound a manned FPSO design aiming at its suitability for an unattended FPSO (Floating, Production, Storage, and Offloading) design with remote operation. This system functional analysis defines each system as not required, required with optimization, required with a new concept, and required with no significant changes. As a result, new system concepts are proposed focusing on moving away maintenance and operational personnel.
Methodology for Forecasting Models of Operational Performance Based on Time Series and Efficiency Benchmarks
Authors: Medeiros B. B. , Ferreira L. L. 
Published: October 2023

Abstract
Production efficiency (PE) is a key performance indicator for the oil and gas industry, as it reflects the ability to optimize resource utilization, reduce operational costs, improve safety, and enhance decision making and planning for operation and project phases. However, PE forecasts often have an optimistic bias and assume constant or flat PE over time, ignoring the effects of aging, maintenance, and operational issues on the production system. This paper proposes a probabilistic PE forecast approach captures the patterns of PE and its components (well, gathering and installation) based on historical data and peer group benchmarking across life cycle. The model follows the ISO/TS 3250:2021 standard for concepts, calculation and reporting of PE. The methodology also shows that PE have a correlation with the operating age of the production system, with shape similar to a bathtub curve (ISO 14224:2016). The implementation of the model improved the quality and reliability of the PE forecast for the company's planning and projects evaluation areas and enabled more effective and sustainable actions to improve PE in the long term. The model also provided more data and insights for decision makers and helped to maintain a more economically robust and resilient portfolio of projects.
A Quantitative Methodology to Introduce a Risk-Based Approach for Integrity Management for Jackets in Brazil
Authors: Sarabi A. , Barbosa V. , Rodrigues R. 
Published: October 2023

Abstract

Objectives/Scope
This paper presents a methodology for the development of the bespoke risk-based inspection plan as part of the structural integrity management process of fixed offshore structures for the coast of Brazil. In this context, it is demonstrated how the local components of a jacket structure, e.g., tubular joints, have to be inspected in a way that the risk of global failure is kept under a tolerable level for extreme environmental scenarios as the platform is aging.

Methods, procedures, process
The global risk assessment follows a quantitative approach based on the jacket's associated Metocean criteria and actual platform's inspection data to calculate the likelihood of failure mechanisms under Metocean hazard.
In addition, a nonlinear finite element structural model is developed to determine the structural redundancy of the jacket structure under extreme storm events. The outcome of the assessment is required to prioritize the tubular joints which are critical to the redundancy of the structure to keep the structure with reasonably low risk of global failure.
In sequence, probabilistic fatigue calculation is utilized to prioritize inspection resources for the tubular joints which are likely to have fatigue failure during extended service life and, at the same time, represent a significant importance to the probability of failure (pf) of the platform.

Results, Observations, Conclusions
The inspection strategy and program, developed in the present study, are focused on the routine underwater inspections, and are based on the recommended practice of the ISO 19901-9 structural integrity management standard.
The methodology is applied for an aged jacket platform in Brazilian waters using the quantitative methodology for RBI plan development. The results of the proposed quantitative risk-based approach are presented to show the advantages of applying a risk-based approach for aged structures.

Novel, Additive Information
In this paper, a comprehensive method utilizing software tools available in the market demonstrates how an operator can approach the issue of defining a more effective inspection program towards risk. This method has been applied to aged assets in Brazil making possible for new operators to continue operating safely in brownfields considering an optimized inspection plan based on the most up-to-date industry standards.
Pore Size Structure Characterization and Poro-Fluid Facies Identification Using NMR Factor Analysis Improve Oil Producibility from Complex Carbonate Reservoir: Case Study from Gulf of Suez, Egypt
Authors: Hakim Emad Abdel , Salim Sadek , Hegazy Amr , Sayed Mayada , Gomes Renata , Saleh Khaled , Ghanim Mohamed , Ghadiry Sherif , Galal Mahmoud 
Published: October 2023

Abstract
The primary challenge posed by carbonates in petrophysics lies in the complexity of their pore systems, which exhibit a wide range of pore sizes within a small section of a single carbonate. In some cases, even the grains possess microporosity, distinct from the porosity between them, resulting in two different pore systems. Understanding the contribution of these pore systems to reservoir productivity is crucial for accurately assessing current and future water saturation levels. Conventional saturation equations like Archie's are not recommended for complex carbonate formations due to uncertainties related to wettability and cementation factors (m and n), which can vary significantly due to diagenesis and fractures. Additionally, the presence of vugs (whether connected or isolated) can substantially impact production and permeability over the reservoir's lifespan.
To address these challenges, this paper introduces an integrated solution that employs nuclear magnetic resonance factor analysis (NMR-FA) in a carbonate reservoir in the Gulf of Suez, Egypt. This approach provides a precise understanding of reservoir quality, enables quantification of hydrocarbon in place, and optimizes oil production. The demonstrated methodology combines NMR-FA with NMR and spectroscopy data, focusing on the characterization of carbonates. By computing poro-fluid facies and integrating them with core data, it becomes possible to accurately determine the volumes of bound and free fluids, thus providing insights into the porosity and quantifying producible hydrocarbons—an influential factor in production. The new bound/free fluid volumes are utilized to calculate continuous NMR permeability, which is then calibrated using core data.
The classification of fluid facies based on pore-fluid porosities enables the evaluation of reservoir quality and identification of the sweet spot—the zones characterized by high producible hydrocarbon porosity and permeability, indicating the best reservoir quality for production.
Considering the complexity of carbonate reservoirs and the presence of secondary porosity is crucial when performing direct volumetric calculations for each constituent poro-facies within the T2 distribution. The results of this workflow successfully characterize the reservoir quality and producibility of the complex carbonate reservoir in the Gulf of Suez, Egypt, pinpointing its sweet spot. Furthermore, this workflow can be applied as a cost-effective solution in various scenarios and formation types.
A Multidisciplinary Approach Including Reservoir Engineering, Petrophysics and Well Performance for a Better Scaling Risk Management in HPHT Wells
Authors: Baraka-Lokmane S. , Mainguy M. , Bouzida S. 
Published: October 2023

Abstract
The interventions on wells such as cleaning and reperforations improve production but not for a long period of time. CaCO3 scale could be the reason for the decline of production; it is therefore crucial to understand the production issues with the objective to design better future wells. The aims of this study are the evaluation of the scaling risk and determination of any link between decline of production, before well intervention, with the scale deposit.
A multidisciplinary approach where analyses from several disciplines such as reservoir engineering, petrophysics and well performance are used for a better scaling risk management in the wells.
This study concerns an Ultra HPHT deep gas condensate Southeast Asian field. No formation water is available; therefore, an analog water has been used for the evaluation of the scaling risk; this water is characterized by a low level of barium; therefore, barium sulphate scaling risk is not expected. The scaling risk has been modelled for the bottomhole and wellhead for individual wells. The results have been analyzed together with the evolution of the production data associated with well interventions. The scaling risk assessment has shown a moderate to a high risk of CaCO3 at bottomhole. The decline of production could be explained by the deposition of CaCO3 at bottomhole, blocking the perforations, this is due to a high drawdown. To reduce the CaCO3 scaling risk at bottomhole, it is recommended to reduce the current drawdown and maintain the bottomhole flowing pressure above the recommended value, depending to individual wells. Some evaporation of the formation water is also possible due to the very high temperature of this Ultra HPHT reservoir. In addition to the reduction of the current drawdown, it is recommended to perform a curative treatment with a help of bull-heading acid wash treatment as soon as a reduction of production is observed. This treatment will help to dissolve the CaCO3 scale at bottomhole, at the perforations and tubing. The scaling risk evaluation shows that as soon as water is produced there is a risk of formation of CaCO3 scale. This risk occurs even with very low production water flowrate. A complementary study including the analysis of the mineralogy and petrophysics of the reservoir, production data, water composition and prediction of the scaling risk has helped to identify the causes of the production decline and propose an adapted scaling risk mitigation for individual wells.