bluuebunny/crossref_metadata_2025_split huggingface dataset:
A New Concept of Corrosion Protection and Integrity of Subsea System in Brazil
Authors: Rocha M. S. , Oliveira J. R. , Silva M. A. , Horta R. M. B. , Brasil S. L. D. C. , Carvalho L. J. , Kassab E. , Souza E. A. , Gomes J. A. C. P. , Hofman T. , Bueno A. H. S. , Miranda L. R. M. 
Published: April 2024

Abstract
Over the past four decades, offshore oil and gas (O&G) production in Brazil has transitioned from shallow waters to deep waters, necessitating considerations for ensuring the integrity of subsea systems in this challenging environment. This study focused on field inspection reports that provided insights into the condition of carbon steel pipelines and subsea equipment, which are protected by galvanic cathodic protection. The findings from laboratory testing and thermodynamic simulations conducted under varying environmental conditions were compared with these evaluations. Additionally, a comprehensive survey of historical shipwrecks, which lacked corrosion protection and had remained on the seabed for decades, was conducted. The preservation and partial integrity of these shipwrecks were inferred from images captured during inspections conducted by remotely operated underwater vehicles (ROVs). By comparing the results of laboratory tests, subsea inspection reports, thermodynamic simulations, and ROV images of shipwrecks, it was observed that the corrosion rate in seawater at considerable depths is significantly reduced. This phenomenon allows shipwrecks to persist on the seabed for extended periods without severe corrosion. Furthermore, the analysis of PETROBRAS technical inspection reports on subsea equipment revealed that components of offshore production systems located in deep waters, which lack effective galvanic cathodic protection, continue functioning without compromising their structural integrity. This analysis supported the investigation of a corrosion protection technique applied to subsea production systems in deep water, based on kinetic considerations that complement existing thermodynamic-based criteria, with minimal risk to structural integrity. Importantly, further investigation is warranted to explore alternative cathodic protection potentials, particularly those exceeding −800 mVAg/AgCl, under high pressure and reduced temperatures. This initiative has contributed to the reduction of CO2 emissions, as there is no longer a need to make two trips to the installation site – one to install the anode skid and another to confirm the reestablishment of the protection potential.
3D Printing Used to Remedy Drilling Total Lost Circulation Events
Authors: Hitchcock G. R. , H. Arfarj M. 
Published: April 2024

Lost Circulation is a well-documented drilling industry issue stemming back to when oil wells were first drilled, and today lost circulation still represents a significant challenge when drilling a well bore. Drilling a well bore using standard drilling practice uses a drilling fluid to act as a primary safety barrier, a drill bit cooling medium and a method to transport drilling cuttings from the well bore. The drilling fluid is continually circulated during drilling operation: down the drill pipe, back to surface up the annulus created between the drill pipe and well bore, drillings cuttings are then removed from the drilling fluid, and the drilling fluid then pumped back down the drill pipe. Lost circulation is where the drilling fluid pumped down the drill string no longer arrives back at surface but leaks into the formation through which the well bore is being drilled. Lost Circulation events can represent well control issues, significant drilling fluid costs, lost time in controlling and/or remedial curing operations. These issues are documented to add millions to the cost of drilling operations annually.
Lost Circulation is described using several categories that relate to the rate of the loss and mechanism of the loss event, these categorized descriptions are then used to catalogue and describe the types of solutions available to cure the lost circulation.
Lost Circulation severity is categorized by the volume of drilling fluid that is lost or not returned to surface. The widely accepted categories used are ‘Seepage’, ‘Partial’, ‘Severe’ and ‘Total’ Losses. Each of the four categories are defined with a fluid loss flow rate, some generally accepted definition rates are shown in Table 1 (Drilling Specialties Company, 2014).
Real-Time Downhole Data Transforms the Efficiency and Safety of Tubing Conveyed Deepwater Multizone Perforation Operations
Authors: Hawthorn A. , Groves D. , Osunjaye G. 
Published: April 2024

Abstract
Tubing conveyed perforating (TCP) is an essential part of the completion in many fields in the Gulf of Mexico and elsewhere. However, there are many risks associated with the operation which can cause significant non-productive time (NPT). These are generally to do with not having visibility of what is actually happening downhole below closed multistage valves. Until recently there has been no real-time data available to understand this. In particular, the pressure reading below the closed valve has not been known. Different operators perforate in different ways as regards the pressure balance in the well, some prefer to perforate over balanced and some under balanced. Before the valve is opened the well is "balanced" to what is assumed to be the pressure regime below the valve after perforation. If this assumption of the pressure is incorrect then the well can either go on losses or can induce an influx into the well depending on whether you are overbalanced or underbalanced to the now perforated zones. This is further exacerbated if you are attempting to perforate several zones in the same run with different zones being at differing pressures in relations to each other. This can cause crossflow and backflow between the various zones making an understanding of what the pressure regime is likely to be more complicated. To counteract this then often in multi-zone wells each zone may be perforated separately with a follow up deburring run in between each perforation run. This method particularly on deepwater vessels can be time consuming and therefore costly, whilst still not knowing exactly what the pressure is under the closed valve after perforation. This paper will demonstrate how an acoustic telemetry and measurement system can communicate data in real-time below the closed valve and then back along the drill pipe to allow for safely managing the well if there is an influx. This allowed multiple zones to be safely perforated in the same run. Additionally, the system can be used for improving the torque and drag models for the subsequent lower completions runs which are difficult to manage in multi zone completions. We will show with data from a sequence of wells how this was introduced and implemented into the tubing conveyed perforating operations eliminating multiple runs and derisking the operations through the use of real-time downhole data. In particular how the processes were changed to deal with influxes over the campaign of wells.
The Journey of CO2 from the Capture to the Subsea Sequestration
Authors: Arcangeletti Giorgio , Di Felice Annalisa , Borghi Davide , Castiglioni Francesco , Ma Jing , Luft Robert , Sun Wei 
Published: April 2024

Abstract
Carbon capture and storage is among a few technologies with the potential to enable significant CO2 emission reductions from hard-to-decarbonize sectors such as offshore production facilities. Within this context, many offshore operators are evaluating measures to reduce Greenhouse Gas (GHG) emissions from their operations including those in Deepwater, and Energy contractors are re-shaping their technological expertise and potential solutions for meeting such challenging and increasing demand for lowering operations emissions.
The present paper will focus on a specific potential application, related to the offshore pipeline CO2 transportation from an offshore capture facility (deepwater or shallow water), to a permanent subsea storage location.
The work presented is the outcome of a joint effort by Exxon Mobil and Saipem articulated through phases:
A framing exercise to shape different scenarios to be analyzed. Engineering execution feasibility screening to characterize the above-mentioned scenarios, and to determine: What are the hurdles for deepwater CO2 capture, transportation via offshore pipeline and its sequestration?
The challenges associated with CO2 transportation via an offshore pipeline, are spread among all the areas characterizing the system, e.g.:
Flow Assurance: the flowing conditions of CO2 are strongly affected by the impurities content, and the bathymetry which the pipeline path traverses. Material Selection: potential corrosion damage mechanisms must be carefully addressed vs. operating and transient flowing conditions. Structural Integrity: the risk of failure associated with potential Running Ductile Fracture (RDF) must be considered and managed since early design phases. Subsea Equipment: the equipment, not limited to the pipeline and riser, shall be assessed in terms of readiness and technological gaps, if any. Safety: the potential risk of subsea CO2 dispersion shall be carefully evaluated. Economics and Supportive Government Policy: Costs are generally key challenges associated with these potential emissions-reduction initiatives.
The study performed covered all the above areas through the involvement of Companies Engineering Departments, SME and Developers. All main building blocks of an offshore CO2 transport system have been analyzed during a high-level conceptual design activity to explore any potential criticality vs. their deployment in the specific application.
Location/asset-specific factors, supportive government policy, and continued technological advancements can be expected to remain important elements in operator analyses of the commercial viability of potential emissions reduction initiatives.
The findings from the presented activity provide offshore Operators considerations for the possibility of transporting CO2 between offshore CO2 capture location to sequestration reservoirs for permanent storage and provide the offshore industry with useful points of reflection.
Experimental Investigation and Deposition Model of Barium Sulfate Scale Deposition in Pipelines
Authors: Chu Guoyu , Chen Mai , Yang Weipeng , Wang Yiwen , Lu Jun 
Published: April 2024

Abstract
Seawater injection, a widely adopted secondary recovery technique in offshore oilfields for enhancing oil recovery, introduces a significant challenge during production – the emergence of barium sulfate scaling issues in pipelines. This issue arises due to the ionic incompatibility between barium-rich formation water and sulfate-rich seawater. Acknowledging the paramount importance of comprehending barium sulfate scale deposition kinetics, this study undertakes dynamic flow experiments to craft a novel deposition kinetics model for the accurate prediction of barium sulfate deposition in pipelines. Using a dynamic flow apparatus, comprehensive investigations were conducted into scale deposition within pipelines under varying temperatures and concentrations, which involved the co-injection of formation brines into reaction tubing. After the injection, an analysis of pipeline dissection was performed to examine the barium sulfate deposition profile along the pipeline. Addressing the intricacies of ion advection, diffusion, reaction, and alterations in pipe geometries simultaneously, a holistic approach was achieved by solving fully coupled fluid flow and reactive solute transport equations. The evolution of reactions on the pipeline's surface was computed using the level set method. The precipitation process of the pipeline was simulated across diverse flow field and response reaction kinetics, culminating in the determination of the reaction rate (K) based on changes in the pipeline's geometric shape. In instances of slow kinetics (Damköhler number &lt;1), nucleation and crystal growth exhibited a more uniform distribution from the pipeline wall. Conversely, for faster kinetics (Damköhler number &gt;1), deposition rates peaked at the pipeline inlet. In such cases, deposition predominantly occurred near the entrance, resulting in a rapid pressure loss.
Repurposing Existing Natural Gas Pipelines for the Transmission of Hydrogen
Authors: Arumugam Ganesh Kumar , Maldonado Ramiro , Thapa Sumil , Mansfeld Andrea , Kamavaram Venkat , Nakatsuka Matthew A. , Nishimura Kevin , Hall Chris , Colburn Adelia K. 
Published: April 2024

Abstract
As the global energy community moves towards the adoption of hydrogen and Natural Gas blends as a potential alternative to existing carbon-rich fuel, it is vital to develop the necessary infrastructure to accommodate hydrogen as a fuel and energy carrier of the future. Newer infrastructure is extremely cost-prohibitive and will significantly delay global decarbonization efforts. Transformation of existing infrastructure in handling hydrogen-based gas blends is the first step in achieving the targeted decarbonization goals.
Although existing natural gas pipelines may be suited for transporting hydrogen-natural gas blends, they are also vulnerable to leaks, embrittlement, and hydrogen-induced cracking, especially on newer high-strength steel (X70 or higher). This paper presents a new approach to preparing existing natural gas infrastructure for potential hydrogen-natural gas blends by protecting vulnerable steel surfaces with an advanced nanocomposite surface treatment. It remains, however, that understanding the impact of cyclic stress, fatigue, and the effect of hydrogen concentration on steel and surface-treated steel is vital to refining and advancing surface protection approaches.
To evaluate field operation conditions, a new experimental facility was set up, capable of conducting high pressure (up to 4000 psi) and high temperature (up to 572°F) testing following ASTM G142. High-pressure testing at 2000 psi in hydrogen blends indicates that the surface treatment has a strong barrier effect and demonstrated a reduction in the susceptibility to embrittlement under hydrogen. In addition, surface-treated coupons were installed in a commercial natural gas transmission pipeline that transports hydrogen (up to 15%)-natural gas blends.
Decarbonization requires newer technologies that are designed to transform the current state-of-the-art energy infrastructure with minimal impact and at a rapid scale. The nanocomposite surface treatment presented here offers a highly scalable solution of in-place treatment of existing natural gas pipeline infrastructure to accelerate hydrogen-natural gas transportation and promote the use of low-carbon energy carriers for the energy industry and its end customers.
Wave Energy Generation Potential in California and on the U.S. Coastline
Authors: Braverman I. , Ratsutskaya V. , Agakolayev E. , Shavit Y. , Tretiakov A. 
Published: April 2024

The global pursuit of sustainable energy sources has driven innovation in the renewable energy sector, with a particular focus on harnessing the power of the waves. The earth's vast expshellanse of coastlines provides an abundant source of wave energy that may be harnessed to provide renewable electricity. According to the Intergovernmental Panel on Climate Change, waves could produce twice the amount of electricity that the world produced at the time of the report (Edenhofer, O. et al, 2011). The potential global energy production from waves is estimated at 29,500 TWh of electricity (Rusu, E., Onea, F., 2018).
There are two main types of wave power plants: offshore and onshore (or nearshore). Offshore wave power stations are located and harnessing energy in deep waters, frequently more than 2 miles from shore, while onshore installations are located on shorelines or near them. Among these endeavors, Eco Wave Power has gained significant real conditions and experience in the generation of clean electricity from the power of the onshore and nearshore waves. This paper focuses on an in-depth overview of the Eco Wave Power onshore and nearshore wave energy generation technology and will then continue to discuss the formulas used by Eco Wave Power for determining the energy generation potential in different sites around the world.
Next, we will provide an overview of our past, current, and future projects, which will include a power matrix and detailed analysis for our real-conditions site in Gibraltar (where we have operated from 2016 to 2022), and provide information from our site in Jaffa Port, Israel (which was grid connected in August 2023). Finally, we will compare the results from our past and current sites to energy production forecasts for the state of California, and for all the United States (including heatmaps and pointing out selected sites in these territories). The goal of this paper will be to show the viability of wave energy in the state of California, and in the United States, while pointing to specific sites within these territories.
Evaluating Subsea Capping Stack Usage for CO2 Blowouts
Authors: Zhou Lei , Upchurch Eric. R. , Liu Yaxin , Anfinsen Bjoern-Tore , Hashemian Yahya , Yuan Zhaoguang 
Published: April 2024

Abstract
Given the challenges posed by CO2's distinct thermophysical properties (i.e., its expansive behavior and attendant risks of causing hydrate, dry ice, and/or water ice formation), a dynamic multiphase flow simulator is employed to evaluate the effectiveness and suitability of using a subsea capping stack to respond to a CO2 well blowout.
A dynamic multiphase flow simulator is used to investigate a capping operation for CO2 well blowouts. Following the typical sequence of a capping procedure and applying a soft shut-in, different primary bore sizes and choke line configurations are considered. Additionally, different reservoir flow rates, fluid types (CO2 and CH4) and water depths are investigated – all with the intention of understanding what differentiates a CO2 blowout from that of methane under varying conditions.
This study reveals that significant hydrate formation on the exterior of a capping stack is most probable for shallow-water, high-rate CO2 blowouts – while the risk of dry ice is non-existent for all scenarios evaluated. Fluid temperatures can plummet to as low as 20° F across the capping stack's body and choke lines, suggesting frozen-water deposition on their exterior. In the context of the CH4 blowouts modeled, there's an absence of the temperature drop necessary to form significant hydrates on the capping stack's exterior. Further, while dimensions of the primary bore and choke lines certainly influence temperature drops, their overall impact is marginal when compared to CO2's supercritical phase transition.
This paper delves into the underexplored realm of using subsea capping stacks for CO2 well blowouts, presenting new challenges and insights not widely discussed in existing literature. For engineers, the insights are useful, highlighting the differential risks associated with CO2 blowouts versus traditional hydrocarbon ones.
An All-in-One Internal and External Coating Material for Enhancing Water Conveyance Pipelines
Authors: Mansfeld Andrea , Nakatsuka Matthew , Mons Ishan , Maldonado Marializ Nieves , Galvan Anika , Elshahawi Hani 
Published: April 2024

Abstract
An in-field deployable nanocomposite material that provides both protection against corrosion and improved pipeline flow capacity will be described in this work. This new approach utilizes a volatile organic compound (VOC)-free, water-based "omniphobic" material that has previously been developed and evaluated for the transport of liquid natural gas. Through the incorporation and refinement of both application techniques and material composition, several new features were added to the initial coating material properties: (1) drag reduction when transporting water or water-based products, (2) resistance to abrasion stemming from entrained solids, (3) UV-resistance to embrittlement and photodegradation, and (4) applicability through spray atomization.
In this paper, we present several case studies to demonstrate the coating application method – an atomized spray application qualified by inspection of the surface to identify applied thickness, coating holidays, and any anomalies. We document how the material can reduce frictional drag forces by 20% over an untreated pipeline, a 5% improvement over a traditional thick epoxy flowcoat material, while showing no abrasive wear even with a flow product containing up to 5% solids. The potential for this coating to also serve as an external corrosion protection solution will be shown, as demonstrated via arc-xenon ultraviolet (UV) radiation exposure of 1,000 hours and field validation at the Daniel K. Inouye International Airport's "reef runway" in Honolulu, Hawai'i. Surfaces protected by the nanocomposite retained their gloss coating and hydrophobicity comparable to pre-UV exposure values. The nanocomposite coating material can deliver substantial cost savings and carbon emissions reductions with minimal disruption operational disruption by extending the lifetime of pipeline infrastructure under a variety of UV, moisture, and temperature conditions.
Structural Constructability for Offshore Brownfield Installation (SCOBI)
Authors: Md Sidek A. M. , Zalahan M. F. , Noor M. N. K. M , Azhar N. A. , Rahman A. R. Abdul , Salleh A. B. , Hassan M. A. I. Abu , Azman M. M. , Shahudin F. , Maarof K. A. , Baharudin A. R. 
Published: April 2024

Abstract
Constructability Risk Management is essential in every project, especially in the upstream oil and gas industry as it covers many stages from concept design to execution at offshore. Hence, understanding of constructability and installability for offshore brownfield modification is crucial. This paper was initiated to address the tacit knowledge, lack of guidelines and scattered references related to offshore brownfield modification project. This paper will provide a guideline on a standardized approach and methodology for structural modification on offshore platforms covering design, onshore construction, offshore installation, and hook-up perspectives based on best practices and lesson learnt comprising platform assessment, cost-benefit analysis exercise and constructability study. The findings were then used to deliver optimized, effective, and safe offshore execution plan. Ultimately, SCOBI will contribute towards sustainable modification project covering cost, schedule, governance, safety, and environment.