bluuebunny/crossref_metadata_2025_split huggingface dataset:
What to Learn from a Hydrate Remediation Operation in a West-African Deep-Water Production Well?
Authors: Alborzi G. , Seal H. , Azarinezhad R. , Watson M. 
Published: April 2024

Abstract
Hydrates are one of the most serious issues in deepwater production systems. Remediation operations are usually time-consuming and expensive, especially if the low-cost methods using the existing infrastructure e.g. injecting thermodynamic hydrate inhibitor (THI) at the vicinity of the hydrates are not feasible or have been tried without any success. Nonetheless, in most cases, should the incident occur, the benefits of removing the blockages and resuming production outweighs the cost of intervention. There are a variety of techniques for hydrate remediation such as using chemicals, mechanical, depressurization and thermal methods. Hydrate remediation operations usually constitutes of a method whereby the ins-situ temperature or pressure conditions are changed in a way that the condition is outside hydrate formation region (HFR). Alternative methods are using THI's to shift the hydrate curves to the left so that the hydrates are dissociated at a lower pressure at the same temperature.
One of the scenarios that carries a relatively high level of hydrate blockage risk is the initial start-up of a brand new well. This work describes a hydrate blockage incident in a West African deep-water infill well tubing, and associated attempts in remediation. The remediation work included forming a team of experts to investigate the root cause of no-flow during the initial start-up, propose the feasible methods to unblock and re-establish the flow using the existing infrastructure such as methanol injection from the wellhead. However, given that methanol could not reach the depth at which the blockage(s) were formed, a Hydrate Remediation Skid (HRS) was hired from the relevant contractors, adequate system isolations were made and depressurization carried out which eventually removed the hydrates and unblocked the production tubing. There has been a number of lessons learnt from this remediation operation which can be extended to other hydrate remediation activities with minor adjustments.
Subsea Reinjection of Methane-Rich Gas: System Design and Injection Pump Testing
Authors: Hill A. C. , Gyllenhammar E. , Olderheim T. , Torres G. 
Published: April 2024

Abstract
Many oil and gas fields rely on gas injection for production support or disposal. However, methane gas injection in an offshore development is energy inefficient, limits throughput capacity, and requires sizeable infrastructure. Hydrocarbon transportation and processing result in pressure losses, which must be compensated for by multiple stages of compression. Subsea reinjection of methane-rich gas is a novel solution that could alleviate the downsides of the traditional topside approach. Subsea processing technologies enable the full reinjection process to occur subsea, without the gas stream having to travel to an intermediate topside facility.
The potential benefits of subsea gas reinjection are significant, and extensive study work and flow loop testing was performed to verify the technical feasibility of this approach. This paper discusses the selection of a subsea gas reinjection concept, system design, benefits, engineering challenges, and successful full-scale, low-density gas pump testing.
Subsea reinjection of methane-rich gas leverages qualified subsea processing technologies using arrangements that are flexible depending on operating conditions. The subsea gas reinjection system design incorporates high-pressure subsea separation to optimize efficiency and liquid yield, while subsea boosting pressurizes the supercritical gas. A comprehensive test campaign validated the ability to pump supercritical gas through subsea single-phase pumps, even for low-density gas applications. With subsea gas reinjection, system efficiency is increased because pressure losses are minimized, emissions are decreased, safety is improved, and flowline and host facility infrastructure can be reduced. Economics are optimized through facility debottlenecking and accelerated production.
Subsea gas reinjection is a novel, promising concept for offshore oil and gas projects. It uniquely repurposes existing technology to improve system performance while decreasing costs, greenhouse gas (GHG) emissions, and complexity. Although system designs for the subsea injection of carbon dioxide (CO2)-rich gas exist, the boosting of low-density methane-rich gas for injection is unprecedented.
STREAM JIP – An In-Depth Study of SCR Response Based on Field Measurements
Authors: Chandra Y. , Deka D. , Campbell M. , Tognarelli M. , Jia L. , Grytøyr G. , de Aguiar L. L. , Rota G. 
Published: April 2024

Abstract
The objective of the STREAM (Steel Riser Enhanced Analytics using Measurements) Joint Industry Project (JIP) is to provide a measurement-based foundation for Steel Catenary Riser (SCR) modelling to ensure that riser response is assessed with adequate but not overly conservative parameters. Insights from phase 1 of the JIP were presented in a prior OTC paper (OTC-29239-MS). In phase 2 which is the subject of this paper, the JIP has conducted a deep dive into several other aspects of SCR design uncertainty including - combined wave and Vortex Induced Vibration (VIV), Motion Induced Vibration (MIV), and extreme storm response.
The paper will describe how field measured riser response events have been categorized into wave, VIV, MIV, and other non-typical response types. Subsequently, fatigue damage rates derived from field measured data (measured fatigue) are compared against global analysis-based predictions.
Concurrent wave and VIV response events are assessed to determine whether the industry standard practice of adding VIV and wave fatigue damage rates is adequately conservative. Measured VIV data is utilized to benchmark SHEAR7 and determine the hidden conservatism in it that stems from non-occurrence of VIV in the field despite the presence of sufficiently high currents. MIV response events are characterized, and the impact on overall riser fatigue is evaluated. Finally, observations field measured riser response during the peak of a major hurricane is reported and examined.
In an industry first, the STREAM JIP has aggregated and analyzed full scale field data from multiple catenary risers. The JIP results provide insights into riser response characterization with potential applications for life extension and more efficient new designs.
Búzios Field: Execution of the 5th Module
Authors: Lopes Jansen , Andrade Priscilla , Juliao Bernardo , Cabral Rafael , Peixoto Ricardo , Lacerda Vitor , Gomes Augusto , Ribeiro Rafael , Aquino Fernando , Junior Delcy 
Published: April 2024

Abstract
The purpose of this paper is to present an overview of the fifth module of Búzios Field Development, its features, and main achievements. It combines innovative concepts and technologies aiming to deal with challenges faced during the execution of Búzios 1 to 4 Projects, producing since 2018.
A robust concept of Subsea, Umbilicals, Risers, and Flowlines (SURF) was implemented associated with an execution strategy designed to reduce the risk of unpreparedness. The strategy integrates critical path analysis, schedule monitoring, and controlling mechanisms to mitigate risks of lack of readiness, streamlining well connections for FPSO (Floating Production Storage and Offloading) ramp-up. Besides that, rigid jumper metrology was taken out of the critical path through the application of indirect metrology between the PLET (Pipeline End Termination) Hub and the Xmas Tree.
The subsea scope was effectively divided into two primary components: an EPCI (Engineering Procurement Construction and Installation) contract for rigid pipe delivery and the utilization of Petrobras’ chartered PLSVs (Pipe Laying Support Vessel) for flexible installation. This approach optimized the installation schedule, ensuring efficient vessel allocation through integrated time, scope, and space monitoring.
The project introduced novel technologies through its FPSO, enhancing H2S removal from the gas export stream using an environmentally friendly solution—a selective membrane system. This innovation promises reduced solid bed consumption, leading to decreased waste disposal throughout the unit's lifecycle.
The methodologies presented help to enhance future offshore endeavors. It outlines a robust SURF concept and execution strategy, minimizing readiness risks and hastening FPSO ramp-up. The integration of critical path analysis, monitoring, and time-scope-space tools offers a distinct approach to concurrent operations. Innovative metrology and H2S removal advancements enhance efficiency and environmental sustainability, respectively.
The first oil of the Project was on May 31st, 2023, and the maximum capacity of the FPSO (150,000 bpd) was achieved just 146 days after that on October 24th, 2023, a Petrobras’ record. The achievement of these milestones is in line with the sound development plan of Búzios Field, which will reach a production of about 1.8 million bpd by 2028, when there will be eleven FPSOs in operation at the area.
Reliability and Quality Management for Technology Qualification of Subsea All-Electric Xmas Tree
Authors: Østebø Runar , Knudsen Tor Willgohs , Sigmundstad Jone Nicolai , Lacerda Alexandre Braga , Popia Fernando 
Published: April 2024

Abstract
Successful technology development and implementation of subsea All-Electric controls systems as an alternative subsea controls system to the traditional Electro-Hydraulic control systems requires high safety and reliability performance. This paper will address how reliability management and functional safety using international standards and industry guidelines have been applied by operator and supplier to qualify such new technology. The new subsea All-Electric control system supports lower carbon and robust design provides cost-efficiency for operators installing such equipment.
Technology development and technology qualification being applied for subsea All-Electric control systems by industry collaboration imply use of qualification processes in which safety, reliability and quality are essential issues. The paper will highlight the novelty of the new subsea production controls design and operational framework and will describe how integration of reliability methods and technology qualification processes can be successfully applied and benefit from standards and operator and supplier governance. A supplier will for example undertake reliability testing and operator will use reliability criteria as part of acceptance criteria for technology qualification approval. The multi-disciplinary use of international standards for reliability management and analyses supplement other subsea technical standards. The use of Reliability Management Programme covering performance objectives expressed by system performance measures, e.g., technical and operational availability, will be addressed.
The added business value of new subsea All-Electric control system as compared to traditional Electro-Hydraulic control system will be described, e.g., reliability-based design, subsea intervention differences and safety and environmental issues. The attention and application of international standards in new technology development have provided improved quality in decision-support essential for an operator to implement and manage risk of new technology. The framework of understanding of the complete subsea production system in which subsea control is one technology element is important to allocate reliability targets that ensures new subsea All-Electric controls is at least similar or better quality than traditional subsea Electro-Hydraulic controls systems.
The paper will demonstrate the benefit in use of international standards for improved reliability management enabling robust design and high quality in decision support for new technology. The paper will also highlight the importance of functional safety requirements compliance balanced with operator performance objectives for uptime for subsea production. This is essential to be a first user of new technology and have quality confidence of the new technology to the stakeholders.
A Subsea Robotics Milestone: Commissioning and Start-Up of UID Operations at Njord
Authors: Cavallini F. , Turi L. , Zornetta G. , Massari G. 
Published: April 2024

Abstract
For many years the offshore industry has been engaged in the definition of how the future of IMR could have been, with operators looking for cost saving and value adding alternatives to vessel based WROV services. Advanced AUV and/or WROV featuring new capabilities have been part of the analyzed set of solutions, till when Equinor conceived the need for a new generation of underwater robots, called UID: the Underwater Intervention Drone. At that time Saipem was engaged in a similar and very challenging effort, and the UID specification perfectly matched the anticipated Hydrone-R capabilities and in particular its residency feature, which is the essential piece to unlock continuous and vessel-free operations, controlling the drone from onshore and relying on its A.I. driven navigation and control system for safe operations.
After several years of preparation activities through the pandemic with consequent delays, the UID has finally hit the water at mid-June 2023, for the long-awaited commencement of the Njord operations. The integration efforts to the Njord-A floater and to the SPS have been substantial in order to allow the performance of resident UID operations both with controls at the rig location and remotely, from the onshore control room in Stavanger. Conducted safely with no incidents to personnel and equipment, the commissioning has been concluded as planned and the UID has become, from the 19th of June 2023, the first resident UID in operations, currently working offshore the Norwegian Continental Shelf in more than 300m of water depth.
This paper is primarily intended to share with the offshore energy industry the main lessons learnt during the UID planning, integration and commissioning phase, and through its first months of resident operations, which are part of a familiarization process truly essential to unlock the full capabilities of the UID. Knowledge sharing on project and interface management, operational aspects and management of expectations will be shared to help the offshore energy industry promoting and adopting such UID technology for the benefit of future operations: cleaner, less risky, more sustainable and cost effective.
Product Development Through Cyclic and Evolving Markets: An Application of Product Platform and Product Family Design Principles
Authors: Ninan Jiju , Shenoy Mahesh , Bansal Gaurav , Meijer John , Bajvani Arshad , Garcia Jorge , Maia Luidi , Eser Hakan 
Published: April 2024

Abstract
Product development in cyclic and uncertain markets is challenging, and continuity in long-term product development can often be lost. Because products developed over multiple cycles can lack commonality in the underlying technology and knowledge from previous development initiatives, it can be almost impossible to reach sustainable economies of scale and drive cost efficiencies. In addition, when similar products are designed and manufactured individually, high design, manufacturing, and inventory costs can result. This presents significant challenges when it comes to product development for both current and future needs.
The concept of product family design has been successfully used in various industries such as automotive, power tools, aviation, and information technology. In one example, this approach was used to successfully head off business challenges by creating a family of products that would be standardized around a robust platform but offer the flexibility to serve multiple market segments via the addition or scaling of features at a minimal cost impact.
To address the product development challenges and reduce costs, product platform and product family design principles were used to successfully develop the next generation of landing string equipment and other derivative products. The development program was executed in four phases. During the first 1.5 years of the program, the product platform was developed. This included extensive tests to establish the platform configuration and its performance limits. In the subsequent phases, the platform was used to develop derivative products for the HPHT landing string and 15,000-psi workover systems. Although the effort to quantify the relationship between the design variables was significant, the data obtained were critical in reducing the development timelines for subsequent products.
The use of product platform and product family design principles reduced the time to market for new derivative products by approximately 40%. The established platform will be used to efficiently generate complementary products, paving the way for structured product development for years to come.
A Geotechnical Acoustic Survey to Address Well Abandonment Options for a Toppled Offshore Platform
Authors: Hoffmann Dillon R. , Guigne Jacques Y. , Laidley Ryan , Kennelley Kevin J. 
Published: April 2024

Abstract
In September 2004, within the Mississippi Canyon Area, a platform was toppled by a subsea mudslide that occurred during Hurricane Ivan. The platform was dragged off the station approximately 700 feet with all the associated well conductors buried under the sediment. Oil continues to flow through these conductors today, which is being collected subsea and sent to shore for recycling.
To permanently plug and abandon these wells using any top kill solution would require knowledge of the conductors’ burial depth beneath the seabed. Standard geotechnical survey methodologies like ground penetrating radar could not determine the depth of conductor burial. An Acoustic Corer1,2,3 survey was conducted to successfully identify the conductors’ location, orientation, and depth of burial.
The Acoustic Core2,3 device consists of a High-Frequency Chirp (HF), a Low-Frequency Chirp (LF), and a Parametric Source. The vertical position of linear features and anomalies is determined by converting acoustic reflection transmission-reception times to depth utilizing a velocity model representative of the survey site. Sixty-three focused Acoustic Corer scans were successfully acquired along four survey grid lines post preliminary scan processing; the sixty-three Acoustic Core data sets were then individually topographically corrected and processed as a singular large area seismic volume encapsulating the whole regions of the four survey grid lines. The data collected along the lines were combined, resulting in 3D views of the sub-seabed down to a depth of approximately 200 ft, and the conductors’ presence, orientation, and depth of burial were highlighted with clarity. This paper will present the results of this survey and the implications of well abandonment options that will adhere to BSEE regulations.
Búzios Capital Projects Synergies
Authors: Nascimento R. , Calegari D. S. P. , Ludolf D. , Weydmann A. , Mendes F. , Naveiro J. , Rosa F. 
Published: April 2024

Abstract
This article presents a case study in which subsurface evaluations regarding projects maturity and its associated risks combined with technological and schedule planning integration between three O&G greenfield Capital Projects have enabled a significant reduction in their stage-gate activity duration, enhanced procurement strategies and mitigation of execution phase risks, thus maximizing asset value.
The adopted approach considered time spacing the three projects and an integrated governance to track projects and expedite decision-making process from concept and technology selection to authorization and execution phases, still allowing for individual project maturity and singularity to be considered. Risk mapping, evaluation and management were also structured from a unified perspective, including those related to the lifecycle of innovative technologies applied. Throughout the whole process, the standardization of documents and project management routines was also carried out.
One of the first observed results was increased agility in the stages of technical specification elaboration, revision, and independent technical assurance, leading to a 5-month reduction in Phase 3, before final investment decision gate coupled with high maturity scores.
The resulting integrated procurement strategy was also successfully executed, maximizing bid attractiveness and critical suppliers’ capacity allocation, thus allowing projects to award long lead items contracts just after final investment decision gate. Synergies between projects such as similarities and time spacing have also enabled contracts to incorporate the possibility of adopting new technologies, e.g., wells completion.
A secondary, but no less important, advantage of this integrated strategy was the reduction in the internal resources required to conduct the time-consuming process of identifying, evaluating and defining mitigation plans for the threats and opportunities of the three capital projects. One example refers to Buzios field gas management which was improved based on the synergies between projects when selecting FPSOs capacities and technologies.
Finally, an innovative approach to decision-making workflow, procurement strategies, and management practices, were essential to ensure the successful alignment of each capital project with corporate objectives, as well as enabling the use of new technologies based on project needs and suppliers’ capacities.
Utilizing Circular Economy and Additive Manufacturing to Minimize CO2 Footprint
Authors: Thomson B. , Coseglio M. 
Published: April 2024

Abstract
The subsea energy industry is under constant pressure, both internally and externally, to provide solutions that better serve the global environment. In recent years the necessity to decarbonize, at every level of the industry, has become one of the most debated concerns globally. The development of additive manufacturing technologies, and their integration into our standard operating practices, presents an opportunity to greatly accelerate our decarbonization efforts. The extent of this opportunity is so vast that we, as a global industry, cannot afford to ignore it.
This paper shall present a case wherein additive manufacturing technologies, namely Laser Powder Bed Fusion (LPBF) and a circular economy mindset were used to manufacture a Tubing Hanger Protector, which is a standard component used in subsea production systems worldwide. The paper shall also cover the series of CO2 footprint calculations that were conducted to underline the potential environmental benefits of adopting such a manufacturing philosophy.
Thorough CO2 footprint calculations are presented for manufacturing with additive manufacturing and a circular economy mindset. These are then compared with CO2 footprint calculations for ‘traditional’ manufacturing, wherein a forging is produced and then machined to create the final form of the component.
On comparing the CO2 footprint calculations for both manufacturing methods, we see a vast difference in the results. A reduction of over eighty five percent is evident, in favor of the additively manufactured part.
Given the built in conservativism of the calculations, i.e. best case data for ‘traditional’ manufacturing and worst case data for additive manufacturing, it is likely that the CO2 footprint reductions stated in this paper are even higher in reality. However, this case study is presented to highlight the opportunities of this type of manufacturing and to serve as a reference to others.