bluuebunny/crossref_metadata_2025_split huggingface dataset:
Taming a Giant: Reservoir Management Strategies to Deal with the Initial Uncertainties in Búzios Field
Authors: Almeida Marcelo , Bukahi Lilia , Carneiro João Paulo , Pires Paulo Roberto , Pitchon Tatiana , Sant'ana Thiago , Vale Pedro Andre 
Published: April 2024

Abstract
The design and development of pre-salt projects prioritized a set of resources and tools for field management, providing greater flexibility in reservoir management strategies. Among these design facilities, the alternating injection of water and gas (WAG) and intelligent completion using interval control valve (ICV) stand out. For the Búzios field, and in specific for Module 4, operated by Floating Production Storage and Offloading (FPSO) P-77, the application of these resources has allowed the unit to maintain high levels of oil production, even in challenging scenarios of delays and low water injection efficiencies and of gas exports, in addition to premature failures observed in equipment and wells. The present work brings a discussion about the use of these flexible resources (WAG, ICV) in Búzios as support for information acquisition, and for the Reservoir Management decision-making process, focusing on the case study regarding the control of Gas-Oil Ratio (GOR) in P-77. Working in a multidisciplinary and integrated way, the results and gains obtained through the conversion of injectors and the performance of ICVs will be presented, which contribute to maintaining the platform's production potential.
A Spatiotemporal Machine Learning Framework for the Prediction of Metocean Conditions in the Gulf of Mexico
Authors: Steele Edward , Chen Jiaxin , Ashton Ian , Pillai Ajit , Jaramillo Sergio , Leung Pak , Zarate Luz 
Published: April 2024

Abstract
Machine learning techniques offer the potential to revolutionize the provision of metocean forecasts critical to the safe and successful operation of offshore infrastructure, leveraging the asset-level accuracy of point-based observations in conjunction with the benefits of the extended coverage (both temporally and spatially) of numerical modelling and satellite remote sensing data. Here, we adapt and apply a promising framework – originally proposed by the present authors for the prediction of wave conditions on the European North West Shelf – to the waters of the Gulf of Mexico. The approach consists of using an attention-based long short-term memory recurrent neural network to learn the temporal patterns from a network of available buoy observations, that is then combined with a random forest based spatial nowcasting model, trained on reanalysis data, to develop a complete framework for spatiotemporal prediction for the basin. By way of demonstration, the new method is applied for the short-range prediction of wave conditions up to 12 hours ahead, using in-situ wave observations from the sparse network of National Data Buoy Center locations as an input, with the corresponding spatial mapping learned from the physics-based Met Office WAVEWATCH III global wave hindcast. The full spatiotemporal forecast system is assessed using independent measurements in the vicinity of the Louisiana Offshore Oil Port, previously unseen by the machine learning model. Results show that accurate real-time, rapidly updating wave predictions are possible, available at a fraction of the computational cost of traditional physics-based methods. The success of the approach, combined with the flexibility of the framework, further suggest its utility in related metocean challenges. While still at an early stage of development into a fully relocatable capability, it is intended that this contribution provides a foundation to stimulate a series of subsequent efforts to help support improved offshore planning and workability – including (but not limited to) applications linked with better resolving spatial variability across renewable energy sites, predicting ocean current regimes in the proximity of oil & gas platforms, as well as informing adaptive sampling strategies conducted by autonomous vessels – where the adoption of such a machine learning approach, that can be run on a laptop computer, having the potential to revolutionize data-driven decision-making by the industry.
Bonga FPSO: Brownfield CSU: Delivering First Time Right SURU
Authors: Gafar Rasheed , Adeniyi Ajibola , Igurube Erhieyovwe , Balogun Kareem 
Published: April 2024

Abstract
The Bonga is Shell’s flagship Floating Production Storage and Offloading (FPSO) facility situated in deep water Nigeria. The facility commenced production in November 2005. As a producing asset, there is statutory requirement to carry out Turnaround Maintenance (TAM) periodically to ensure continued asset integrity.
Facility startups, especially after a prolonged period of shutdown, have always been a source of concern to facility managers. There is always the risk of start-up issues which can delay ramp up to steady state operations with the attendant loss in revenue and reputation. This value erosion has also been witnessed on Bonga FPSO after previous TAMs. The TAM team therefore sought an improvement in this area to complement the already well-established successful areas of Safety and schedule optimization.
Key to this success was the utilization of a Project tool in the Commissioning and Start Up (CSU) toolkit, a World Class Start Up and Ramp Up (WC-SURU) assessment. The WC-SURU exercise was aimed at mitigating against the often-experienced value erosion associated with start-up and ramp up resulting in delay in attainment of steady state operations. This paper discusses the implementation of the scenario thinking using the WC SURU methodology for the Bonga TAM of 2022, the successes, the lessons learnt and the opportunities available for further use of different tools.
Hydraulic, Chemical, and Mechanical Response of Sandstone Rocks for CO2 Storage Systems
Authors: Shandilaya Shivesh , Roshankhah Shahrzad 
Published: April 2024

Abstract
Carbon dioxide storage in sandstone formations with desirable permeability represents a viable method for reducing atmospheric CO2 levels and mitigating climate change. In this laboratory study, we investigate the response of a dry Navajo sandstone specimen to constant-rate water injections under vertical loading up to 12 MPa and zero lateral strain conditions. Our measurements and analyses include identifying the heterogeneity features in the internal structure of the rock via X-ray imaging, the geochemical composition of rock minerals via XRD and XRF, the evolution of the axial load and deformations, and fluid pressure upon injection, and the full-field planar deformations on the rock surface through digital image correlation. The initial goal was to understand the fluid flow regimes ranging from diffusive flow to localization of fractures induced by water injection; however, the high permeability of the sandstone would require higher injection rates than the range available in the current pumping system. The results enhance our understanding of fluid flow and damage mechanisms in the near wellbore region, utilizing a multi-phase, multi-scale, and multi-sensor monitoring system to overcome the limitations of traditional single-sensor measurements.
Anchor Project: Strategies and Approach in Managing the Evolving HSE Risks on a Major Capital Project
Authors: Beyer J. , DeKoker T. , Mohile T. , Rankin B. 
Published: April 2024

Abstract
The Anchor floating production unit (FPU) is a Chevron Gulf of Mexico (GOM) facility located in approximately 5,000 feet of water with a nameplate capacity of 75,000 bopd and 28 mmscfd with future expansion capability. The Anchor development plan consists of seven wells tied back to the FPU through dual flowlines from two drill centers with produced oil and gas transported via export pipelines. This paper will provide an overview of the Health, Safety and Environment (HSE) strategies deployed in support of the design and execution of the Anchor project. It will share key successes and lessons for managing and navigating an evolving risk profile from engineering through fabrication to offshore installation. It will also detail the comprehensive approach used to manage key HSE risks.
The Anchor project used several tools and processes to steward HSE. This comprehensive approach included inherently safer designs and HFE, implementing effective programs to prevent serious injury and fatalities, integrating human and organizational performance (HOP) concepts across all phases, implementing lower carbon initiatives, building a genuine care and concern culture, inclusion of craft-led safety organizations in planning and executing the work and partnership with contractors.
During early project phases, the application of HFE allowed for long term HSE success to be built-in well before fabrication or operation of the facility. Early fabricator/contractor engagement allowed for their expertise on constructability and work execution to mitigate risks and reduce rework and out of sequence work. During work execution, multiple fit-for-purpose safeguard validation and verification programs were implemented. These assurance activities helped manage the hazards and risks that were assessed at Anchor's various work sites - ensuring we moved from "I think" to "I know" it is safe to commence work. Anchor partnered with contractors to use their proven HSE management programs and collaborated with them on the HSE journey to address any potential gaps. Multiple elements enabled the development of a strong safety culture. HOP helped build error tolerant systems and guided the response when things did not go as planned. Organizational learning concepts allowed development of stronger safety programs in a psychologically safe way. Involving the craft workforce in all these elements built ownership of HSE programs and a "speak-up" culture.
This paper will provide additive information on HSE initiatives to protect our workforce, the communities we work in, the environment, and our assets.
CCS Opportunity Along the Gulf Coast Corridor
Authors: Grant T. C. , Morgan D. J. , Cunha L. B. , Vactor R. T. , Hoffman H. E. 
Published: April 2024

Abstract
Carbon capture and storage (CCS) activity along the Gulf Coast from Corpus Christi to the Mississippi River and in state waters of the Gulf of Mexico is increasing. ExxonMobil, Chevron, Talos, Denbury, Occidental, Repsol and many other companies are forming partnerships to take advantage of evolving business opportunities or government co-funding of CarbonSAFE projects.
The Gulf Coast corridor, onshore and offshore, from Corpus Christ to the Mississippi River presents a high concentration of CO2 from industrial sources and excellent storage reservoirs in the underlying Cretaceous and Tertiary sands. Analysis of the technical, geologic, economic and social aspects of this CCS opportunity is necessary for successful deployment of CCS technology and eventual attainment of NetZero goals.
To provide analysis of the CCS opportunity along the Gulf Coast Corridor, the National Energy Technology Laboratory (NETL) has developed a CO2 Transport Cost Model and an Onshore CO2 Storage Cost Model. Nearing completion is the Offshore CO2 Saline Storage Cost Model. These models can provide comparative analysis of storage and transport opportunities for multiple CO2 sources to storage locations onshore, offshore or between either.
The Onshore CO2 Storage Cost Model is aligned with EPA’s Class VI regulations which are also applicable in offshore State waters. Carbon dioxide storage regulations for offshore operations in Federal waters are being developed, built upon existing offshore oil & gas operations but are expected to dovetail with onshore Class VI regulations to minimize any conflicting requirements.
Financing CCS project development and operations is a primary challenge that is evolving towards a solution. A key component here is the 45Q credit, which in turn will support offtake agreements between a source and storage operations.
Initial industry interest in the Gulf Coast region presents an opportunity to examine business opportunities for deployment of CCS technology in this area, either onshore, offshore of both.
Drilling Automation - An Engine of Change for Risk Prevention Offshore
Authors: Goodkey Brennan , Fabo Andrew , Le Buhan Francois , Cahalane James , Bisht Sameer 
Published: April 2024

Abstract
This paper delves into the evolving landscape of drilling automation, emphasizing the imperative for these systems to go beyond novelty and deliver quantifiable financial value. With drilling automation maturing over time, expectations are rising for tangible benefits in terms of performance and risk reduction and resulting material costs savings. The paper presents a case study centered on several offshore drilling operations that exemplify the successful implementation of a closed-loop drilling automation solution and the positive impact these technologies can have on the bottom line. Encompassing the entire drilling workflow, from tripping and connections to on-bottom drilling automation and trajectory control, a suite of innovative technology spanning domains and systems will be summarized. What sets this case study apart is the specific focus and prioritization of the requirements and challenges inherent in offshore drilling automation compared to its onshore counterpart. The technology deployed in this case study was not only tailored to the specific considerations of offshore drilling, but was also adapted over time to continually maximize the value added. The paper underscores the significance of a focused approach in identifying and managing the unique risks and priorities associated with offshore drilling. The success of the closed-loop drilling automation solution lies in its adaptability and responsiveness to the dynamic offshore environment, showcasing a paradigm shift from mere technology deployment to strategic adaptation that delivers measurable financial benefits.
Appraising Carbon Geological-Storage Potential in Saline Aquifers Using Pressure-Transient Analysis
Authors: Zhang Qiang , Zhang Fengyuan , Rui Zhenhua , Xu Minghao , Lu Ruihan 
Published: April 2024

ABSTRACT
Pressure transient analysis (PTA), as a powerful technique for CO2 injection data analysis, plays an essential role in assessing the CO2 storage performance of saline aquifers. However, the appearance of the two-phase CO2/brine flow together with pressure-dependent properties introduces significant nonlinearity into the governing equation and makes the use of PTA erroneous. Accordingly, we presented a two-phase approach to estimate the storage capacity and spatial distribution of CO2 plumes by analyzing injection data.
The proposed method consists of an analytical two-phase flow model for CO2 injection in saline aquifers and a straight-line analysis approach for estimating the CO2 storage capacity. The PTA model incorporates the two-phase flow of CO2-brine, and the boundary condition of moving CO2 injection front by employing a modified equation of the distance of investigation. To account for the pressure-dependent reservoirs properties, we established new definitions of pseudo-pressure and pseudo-time and reached the analytical solutions. In addition, approximate solutions in straight-line form are obtained to appraise the CO2 storage potential through an iterative workflow.
We assessed the precision of our proposed method by conducting tests with synthetic data. This data was generated from four numerical cases related to CO2 storage in saline aquifers, simulated under constant injection rate and bottom-hole pressure conditions. We presented a two-phase diagnostic plot to identify transient and boundary-dominated flow regimes. A two-phase specialty plot is proposed to calculate essential reservoir parameters and the CO2 storage capacity. The numerical validation confirms the accuracy of the proposed method with an extremely low relative error in estimating CO2 storage capacity. The good match demonstrates the superiority of the proposed method in the quick evaluation of storage potential over the numerical simulation. Additionally, the method offers early detection of leakage through the prediction of the CO2–brine front.
Instead of assuming constant CO2 properties in two-phase PTA, this paper incorporates pressure-dependent fluid properties into a straight-line analysis approach by defining new pseudo-properties. Unlike the prior single-phase model without an injection front, the moving boundary condition of CO2 injection front is considered in the superposition pseudo-time to provide a more accurate estimation of CO2 storage capacity. This study shows that the use of PTA along with a simple CO2 injection model is simple yet rigorous for CO2 storage projects.
Dashboard for Marine Energy Site Assessment and Monitoring
Authors: Flanary C. , Jones C. , Ellenson A. , Nelson T. 
Published: April 2024

Abstract
The marine energy (ME) industry presently relies upon fragmented site assessment solutions that require high resource expenditure for deployment at each site and do not leverage the wealth of readily available tools and information. A wave energy resource assessment dashboard, currently in development, will substantially improve siting, permitting, operations, and maintenance of ME projects by providing an integrated solution that is a one-stop-shop for a developer's needs. The Site Energy Assessment and MOnitoring Dashboard (SEAMOD) will be of commercial interest to anyone seeking to deploy an ME project and is easily expandable to include tidal and wind energy site assessments. The integrated dashboard is being developed using state-of-the-art database and cloud computing methods and data-assimilative modeling tools that can be coupled with low-cost, rapidly deployable wave buoys and environmental sensing hardware. The combined software and hardware dashboard will reduce wave energy site characterization and wave climate monitoring costs by more than 60 percent and provide assessments that meet international industry standards. The final integrated dashboard provides a low-cost solution that delivers comprehensive, scalable, industry-standard energy resource assessments and offshore characterizations required for successful ME development. The integrated dashboard offers visibility of the most recent site modeling, measurements, and historical data. The application and integration of consensus-based standards for wave energy resource assessment, as determined by the International Electrotechnical Commission (IEC), are crucial for the impact and value of SEAMOD. SEAMOD includes monthly, seasonal, and yearly statistics, as well as the total 30-year record, offering temporal resolution of the IEC parameters to aid potential developers in determining the available wave energy resources in their area of interest.
To realize a thriving global ME industry, the physical environment at a potential deployment site must be understood, not only for resource characterization, but also for optimization of device and power conversion performance. SEAMOD directly addresses these needs with a commercially marketable product. SEAMOD is a low-cost solution that provides comprehensive ME resource assessments, baseline environmental monitoring, and offshore characterizations required for successful ME development.
Demonstrating the Accuracy of a Novel Modification to Cubic EOS to Predict the JT Effect Using Field Data
Authors: Singh J. , Shirani F. F. , Erickson D. 
Published: April 2024

Abstract
Joule-Thomson (JT) cooling plays an essential role in the flowline's design phase. It is one of the defining factors for pipeline minimum temperature. Therefore, it controls the pipe's alloy selection based on its minimum allowable temperature. Additionally, JT cooling impacts hydrate control. Common design models can overpredict the JT cooling value. This leads to extra CAPEX and OPEX costs. This paper will use data from nine fields to demonstrate the accuracy of cubic EOS's ability to predict JT cooling out of the box and with tuning.
The cubic EOS was modified to shift the enthalpy curve to improve the JT cooling prediction across the choke. For this study, the measured pressures and temperatures before and after the choke for 28 wells located in 9 different fields across the world were analyzed. This data was fed into a thermodynamic simulator to calculate JT cooling for both the original and modified cubic EOS. A comparison between the JT cooling values calculated by both methods with the actual data from the field demonstrated the improved cubic EOS's ability to predict JT cooling accurately.
It was noted that the JT predicted by the modified cubic EOS was much more accurate to the temperature drop across the choke in the field. The reason for inaccuracy in the original cubic EOS is that there are limited terms in the equation to predict the change in enthalpy due to pressure. This inaccuracy can be specially noted at higher pressures where the EOS predicts a lower density this can results in large errors in the JT prediction (typically too low). Using the improved cubic EOS can accurately predict JT cooling value and ultimately leads to improved predictions for online model. It also provides an idea of the margins which should be looked at for the design of areas where JT occurs in the field (choke and topside control valves).
Life Cycle Assessment of Oil and Gas Drilling Activities
Authors: Carvalho B. C. , Souza H. R. A. , Soares S. R. , Fontes M. A. , Gomes E. J. , Marinho L. S. , Junior W. F. C. , Calderari M. R. C. M. 
Published: April 2024

Abstract
A Life Cycle Assessment (LCA) study is presented for the comparative evaluation of environmental performance across different drilling scenarios, in the context of offshore oil and gas well operations. Particular emphasis is placed on offshore and land pathways for treatment and final disposal of drilling fluids and cuttings. The LCA model was developed in accordance with ISO 14040 and 14044 standards, encompassing distinct life cycle stages: fluids manufacturing, inbound logistics, drilling operations, outbound logistics, and end-of-life treatment and disposal. Six scenarios, involving diverse combinations of water-based (WBDF) and non-aqueous (NADF) drilling fluids, and three end-of-life alternatives—offshore disposal, industrial landfill, and incineration—were systematically assessed and compared. The Life Cycle Impact Assessment (LCIA) method employed was ReCiPe (H) Midpoint 2016, and the considered impact categories were climate change, particulate matter formation, freshwater eutrophication, marine eutrophication, freshwater ecotoxicity, and marine ecotoxicity. Among the lifecycle processes, logistic operations were found to have the lowest environmental impacts across all categories. The drilling phase exhibited significant influence, particularly in climate change and particulate matter formation. The fluid formulation phase, specifically in scenarios involving WBDF, prominently affected both freshwater eutrophication, marine eutrophication, and freshwater ecotoxicity. Marine ecotoxicity was mostly influenced by the end-of-life stage in scenarios involving offshore disposal. For five of the six impact categories, the scenario with the best overall environmental performance was drilling with NADF and offshore cuttings disposal, due to the greater performance of this type of fluid in drilling processes and the reduction in environmental impacts associated with avoiding onshore treatment and final disposal. Conversely, the discharge of cuttings into the sea had a pronounced impact on the marine ecotoxicity category due to the potential toxicity of substances such as copper, barium, and zinc. Among terrestrial treatment options, scenarios involving incineration were consistently more environmentally impactful across all impact categories. The findings of this LCA study offer a robust technical-scientific foundation, facilitating informed discussions and aiding decision-making processes regarding the environmental impacts of oil well drilling operations. This pertains particularly to the choice of drilling fluids and the management of drilling waste within this industry sector.