bluuebunny/crossref_metadata_2025 huggingface dataset:
Pre-Metrology in Subsea Rigid Jumper Tie-In as a Key for Anticipating First Oil
Authors: Peixoto R. P. M. , Cabral R. C. N. , Loureiro W. C. , Vargas T. B. , Juliao B. Q. , Yohou M. , Volpi E. , Bianco B.
Published: April 2024

The use of rigid pipelines in underwater engineering projects is based on their proven robustness and extensive history of use in the oil and gas industry. However, market limitations and challenging schedules are offensive agents to this type of architecture that need to be mitigated and overcome to add flexibility to the project and optimize resources utilization.

One of the main limiting factors of the rigid pipeline-based underwater architecture is the connection with subsea equipment. Typically, this connection is made through rigid jumpers between a Pipeline End Termination (PLET) installed at the end of the flowlines and the connection point with the subsea equipment, usually a Subsea Christmas Tree or subsea equipment, such as manifolds or boosting units. In order for these jumpers to be properly connected, it is necessary for the pipeline and equipment to be already in place and for metrology to be performed: their positions must be measured, and tolerances determined before the jumper can be manufactured and installed.

As a common practice during the interconnection phase of the rigid pipe-based subsea architecture, it is necessary to perform precommissioning steps of the rigid pipeline, including flooding and hydrostatic testing, followed by metrology between the PLET and the Subsea Christmas Tree hubs. The manufacturing process of the rigid jumper that connects the rigid pipeline to the subsea equipment, including the final welding and testing is only performed after this metrology process. This takes a certain amount of time with direct impact on the critical path for the readiness of the subsea system of the project.
A Critical Appraisal of Seismic Cone Penetration Testing
Authors: Verbeek G. E. , Masters T. A. , Czech T. , Sullivan C. , Cambeilh C.
Published: April 2024

Abstracts

The Seismic Cone Penetration Test (SCPT) is widely considered the most reliable tool to determine the in-situ Small Strain Shear Modulus (Gmax) profiles. These profiles can then be used as direct input to design models for e.g., offshore windfarm foundations. However, although SCPT has been performed routinely on land for many years, the complexities of performing this kind of testing with a seismic source located on the seabed and the subsequent data analysis presents ongoing challenges for the industry. The lack of standardization of the equipment used for the test, the set-up on the seabed, the data obtained during the test and the methods for interpretation can easily lead to difficulties for practicing engineers to establish the reliability of the generated data sets, and thus the analysis outcome. The authors provide a critical review of the acquisition methods commonly utilized and how these affect the quality of the acquired data and the derived results. An appraisal of the advantages and disadvantages of true interval straight ray path and pseudo interval true ray path processing methodologies is presented along with alternative recommendations for developing design vs profiles.
Reuse of Flexible Pipes in Revitalization of Brown Fields
Authors: Loureiro W. C. , Gasparetto V. , dos Santos F. P. , Campello G. C. , da Silva A. H. , Rocha D. M. , Teixeira S. C. , Chaves E. G. , de Souza R. F.
Published: April 2024

Flexible pipes tend to be complex structures, tailor-made, and require a significant amount of engineering in preparation for manufacturing and delivery. These features increase the cost and the time required between procurement and delivery, extending the project schedule significantly. On the other hand, several wells may have their operational life shortened due to reservoir management strategies. To make ends meet, Petrobras has established procedures to evaluate the integrity and the possible reuse of flexible pipes, which are removed from the field with remaining service life, in new wells. This paper outlines how Petrobras, drawing on the knowledge gained through years of operating flexible pipes, along with extensive qualification programs and inspections, developed and certified methodologies and digital tools to enable, enhance and streamline the evaluation the reuse of flexible pipes in new applications. The reuse of flexibles became possible through development of an extensive material database, in-house web-based digital tools to verify permeation, polymer aging, and execute local and fatigue analysis. These tools were calibrated through years of data, as full-scale fatigue testing (tension and tension and bending), information from operational monitoring and historical field failures. The integration of these digital tools and databases allows engineers to quickly identify the best candidates for reuse in new projects. They gather all relevant compatibility analysis with new application, operational history, and integrity management information for each selected pipe, avoiding the need to go through extensive searching of each individual inspection report, production records, and input data in the analysis tools. In the last five years, over 420 km of pipes have been reused. This number tends to increase even more as more precise operational data becomes available and more integrated tools and databases are employed. The reuse of flexible pipes saves resources, time, capital expenditures (CAPEX), anticipate projects, and mitigate CO2 emissions by avoiding manufacturing new pipes.
Comparison of FEED Level Design and Performance of Chain Catenary and Synthetic Mooring Systems for a 10+ MW Floating Offshore Wind Turbine
Authors: Ward J. C. , Hallowell S. T. , Kim N. , Viselli A. M.
Published: April 2024

Floating offshore wind platforms share many similarities with oil and gas platforms. However, the fundamental differences between the two floating structure applications necessitate innovative requirements and design philosophies. Using synthetic fiber ropes in intermediate- and shallow-water mooring systems is an example of innovation that increases the likelihood of widespread floating offshore wind commercialization. This study compares the FEED level design of a conventional chain catenary mooring system with an innovative semi-taut polyester mooring system for an 11+ MW floating offshore wind turbine located off Monhegan Island, Maine. The study uses site-specific metocean, geophysical, and rope test data to demonstrate the benefits of a semi-taut polyester mooring system compared to a chain catenary system.
Review of Human Reliability Assessment Methods
Authors: Reis A. G. , Neves R. A. , Ceni R. , Costa M. M. , Andrett F. V.
Published: April 2024

Constellation, an oil development company operating drill ships and semisubmersible platforms in water depths of up to 12,000 feet, is innovating with dynamic real-time monitoring of operational safety barriers of rigs. This article aims to compare Human Reliability Assessment (HRA) methods for Offshore Drilling Operations. The study encompasses 18 methods: THERP, ASEP, HEART, SPAR-H, ATHEANA, CREAM, APJ, PC, SLIM-MAUD, HRMS, JHEDI, INTENT, CAHR, CESA, CODA, MERMOS, NARA and PETRO-HRA. The analysis considers applicability, effort, complexity, level of detail, data availability, expertise, and resources. The article provides industry professionals with insights for informed decision-making, enhancing safety and efficiency in Offshore Drilling

The evaluation of Human Reliability Assessment (HRA) methodologies for offshore drilling operations yielded insightful results, among the 18 assessed methodologies, emerged as the top-ranking methods in terms of applicability, effort, complexity, simplicity, level of detail, data availability, expertise, and resource requirements. These methodologies demonstrated high applicability to Offshore Drilling, providing comprehensive analysis capabilities. They exhibited a balanced approach, considering Human Factors along with other risk factors. However, it was observed that some methodologies required a higher level of expertise and effort, while others offered greater simplicity and ease of use. The conclusions drawn from this study emphasize the importance of selecting an HRA methodology that aligns with the specific needs and resources of Offshore Drilling operations. Organizations should consider the unique characteristics and challenges of their operations when choosing a methodology. Additionally, regular reviews and updates to the chosen methodology are crucial to ensure its continued effectiveness. This research contributes valuable insights for industry professionals, aiding them in making informed decisions to enhance safety and efficiency in Offshore Drilling operations. Further research is recommended to explore the practical implementation and long-term performance of the selected methodologies in real-world offshore drilling scenarios.
Well as a Service – Is it Possible to Produce with Safety, Reliability, and Cost Efficiency?
Authors: Colombo D. , Junior F. C. C. , Junior I. I. , Almeida L. M. de , Nóbrega M. V. , Pedrassa M. H. , Roman R. S. , Zanetti A. A. , Radespiel E. S.
Published: April 2024

The paper presents how the well integrity management system has evolved from a qualitative failure model to a novel data-driven approach using quantitative risk evaluation. This evolution allowed well integrity management to stop being a burden for operating companies and become an opportunity to improve efficiency and create value for their assets. The goal has shifted from constructing the wells in the cheapest and fastest way to providing production availability with cost efficiency, safety, and reliability; aiming to reduce carbon emissions. The concept and implications of this new paradigm, named Well as a Service will be described in the paper. This requires improvement in the design of the well, planning, and management of resources to guarantee operational readiness, integration with production, and clear safety and integrity controls.

The paper focuses on a new set of engineering tools that made Well as a Service possible. In the data-driven approach, different sources of information, such as the reliability history of wells and the real-time monitoring systems must be the centerpiece. New KPIs and criteria for managing the wells are also required. To illustrate how these tools can act combined to support planning and decision-making, some examples will be presented: how to select the best well design, how to manage the portfolio of wells, or make decisions related to a single well integrity failure.

The tools were inspired in the industries that are the benchmark in asset management such as aerospace and nuclear industries. The tools were developed each one for a specific purpose, for the design phase and the operational phase, for the safety and integrity aspects, and for the economic aspects. The correspondent performance indicators were developed as well as the acceptance and target criteria. The combination of tools, indicators, and acceptance criteria results in a panel that allows the management team to plan the resources and make decisions regarding the health of the wells. With the appropriate process, these technologies have generated value while maintaining or even increasing the safety of operations.

Finally, the paper will discuss the next steps in terms of technology to support Well as a Service. The future of risk-based decisions is condition-based, where not only probabilistic analysis provides optimal decisions but by measuring the current health of the components and predicting, based on degradation modeling, their performance in the future will allow deep discussions about remaining useful life, life extension, abandonment and influence the industry in the qualification process for new technologies.
Using Additive Manufacturing Technology as a Game Changer in Subsea Operations
Authors: Silva C. J. , Santana A. L. , Souza D. O. , Lopes V. S. , Martins F. J.
Published: April 2024

The study aims to demonstrate the potential in using additive manufacturing to create tailored tools to enable underwater intervention operations in complex scenarios in a diverless manner with ROVs (Remotely Operated Vehicles) in shallow waters. The approach was through modeling, simulation, manufacturing, testing and piloting of tools for underwater intervention operations. Pilot production demonstrated the viability of the technology at its current maturity. The combined use of different strategies for using technology will allow gains in all aspects evaluated: Reduction in lead-time for emergency purchases of up to 200 days, average in cases where the original manufacturer of the part does not have it available for immediate delivery; Reduction of up to 12% in the evaluated spare parts stock, with annual economic gains that can reach up to 2.5% of the amount stored; This is an additional alternative for obtaining parts that are difficult to acquire (for example, obsolete). The novelty is the use of Additive Manufacturing to manufacture custom-made parts with a better weight/mechanical resistance ratio. Other advantages of this approach can be mentioned, such as reduced lead time and inventory, with a virtual database, functioning as a repository whenever necessary, with demonstrated gains, in a pilot, for special underwater intervention operations, especially in prototype tools for ROVs to operate in shallow waters. Using this strategy can enable complex subsea operations in the oil and gas industry.
An Innovative and Low Carbon Approach to the Development of Brazil's Largest Gas Project
Authors: Ballesteros Sergio , Seljebø Steinar
Published: April 2024

Equinor (hereafter also referred as ‘The Company’) is undergoing an internal transformation reflected not just in its culture but also in its operations and investment portfolio. At the core of this transformation is a strategy built around The Company's commitment to reducing its carbon footprint and becoming net-zero by 2050. Relative to 2015, The Company is set to have a 50% net reduction in operated emissions and an upstream carbon intensity of ~6 kg of CO2 per barrel of oil equivalent (boe) by 2030. One notable area in this space is the decarbonization of Floating Production, Storage, and Offloading (FPSO) units, which play a crucial role in offshore hydrocarbon production.

The Company's decarbonization activities permeate throughout its management system. In this context, The Company sets clearly and rigorously that projects be evaluated under the Best Available Technique (BAT) principle. These evaluations include scrutiny and screening of the technologies and processes that deal with specific pollutants onboard FPSOs and fixed installations, from noise and discharges during drilling operations to solid waste and fugitive emissions. Assessment of emission reduction potential, abatement cost, benchmarking, experience sharing, and environmental budgeting are important elements in the definition and delivery of successful energy efficient projects.

The Company has had a presence in Brazil for more than two decades. The Raia project (former BM-C-33) is a consortium made up of Equinor (35% and operator), Repsol Sinopec Brasil (35%), and Petrobras (30%), which represents the third FPSO unit to be put on production and operated by The Company after Peregrino and Bacalhau. The $9 billion development, located in the Campos basin at a 2900 m water depth, is a gas and oil/condensate project that will process liquids and gas to sales specifications onboard the FPSO. The offshore gas processing is based on an innovative concept and first of a kind in Brazil. With a production start in 2028, the project is to recover above 1 billion boe and deliver 15% of Brazil's entire gas needs. Emission abatement technologies to be implemented onboard the FPSO include: combined cycle for power generation (CCGT),closed flare and cargo vent systems,variable speed drive (VSD) on large compressor drives and,turbo expanders (TEX) for hydrocarbon (HC) dew pointing.

The most significant success in the decarbonization onboard the FPSO is the use of a CCGT for power generation. The technology relies on excess heat recovery and a steam turbine. Through this and additional measures, the Raia project was able to shift its carbon footprint by around 64%, resulting in an intensity of 5.6 kg/boe. Further optimization and operational experience could improve the project's carbon intensity. For example, by increasing gas export rates or maintaining controlled flaring during start-up and commissioning activities.
Resident AUVs: Enabling Efficient Operations and Improved Asset Integrity Through the DeepStar AUV Docking Station Standardization Program
Authors: Mehta S
Published: April 2024

Resident Autonomous Underwater Vehicles (AUVs) reduce the associated vessel days and Green House Gas (GHG) emissions of offshore operations. Hosted subsea, resident AUV's would provide improved asset integrity through early identification of integrity issues and increased availability for inspection and intervention. Developers offer customized solutions for docking, power and communication. While customized stations offer bespoke advantages, each installation requires significant cost and design effort for integration into a Subsea Production System (SPS). This is a barrier to adoption. DeepStar®, an operator-funded Research & Development joint industry consortium, sanctioned several programs on accelerating the industry to a unified set of standards and operating practices for the integration and utilization of field resident AUVs within offshore fields. DeepStar CTR: 18302 - Standardization of AUV Docking, was focused on harmonizing existing AUV docking stations concepts to enable implementation at scale. As part of this project, existing information was gathered and critically reviewed a to highlight discrepancies and propose recommendations to API 17H to achieve alignment among other standards and the industry. There are several standards which relate to AUV docking station interface design and were the original foundation documents used in this study: API 17H, DeepStar CTR 11304, and ongoing work from SWiG.

The team defined the project framework including the attribute definitions to be used for comparison and the classification of the information. API 17H 3rd Edition was used as the baseline standard. Therefore, attributes were classified ‘in agreeance’ or ‘discrepancy’. A second level of classification was also attributed to comparisons which were ‘Numerical’ or ‘Qualitative’. The project team had to agree on the credible sources of information to be input into this assessment. The Subsea Wireless Group (SWiG) a Joint Industry Project (JIP) dedicated to developing standards for subsea wireless communications was identified early as a contributor. The SWiG JIP were developing the first industry standard defining the power and communications requirements for inductively recharging an AUV at a subsea docking station. Other contributors included leading resident AUV developers. Their feedback had to be carefully managed to avoid conflicts of intellectual property and competitive advantage. Equinor was also a key contributor due to their development of the UIDTM Subsea Docking Station.

From the analysis performed within this project, several gaps and recommendations were identified to be incorporated within the next revision of API 17H. Attributes where API 17H deviates from DeepStar have supported reasoning. For the most part, these discrepancies have been marked as "Keep API as is". Due to API 17H 3rd Edition having minimal requirements for power and data transfer, a significant percent of SWiG input was considered as additional attributes.
Detailed Modelling of Displacement and Hot Oiling of a Waxy Non-Newtonian Fluid in a Mature West Africa Deep Water Production Facility
Authors: Seal H. , Alborzi G. , Watson M.
Published: April 2024

This study investigates the feasibility of a changeover of displacement and hot oiling fluid from diesel to dead crude in a mature West Africa deep-water production facility from a flow assurance perspective. It addresses the practical challenges associated with the dead crude displacement and hot oiling procedures as well as the technical challenges of transient modelling of a waxy non-Newtonian fluid through both insulated and uninsulated piping. Modelling was performed using commercial software packages to simulate the existing diesel displacement and hot oiling procedures and to tune the model of the system to data from the field. The non-Newtonian behavior and wax precipitation and deposition properties of the dead crude were then characterized and tuned based on laboratory rheology and flowloop testing. Cases of dead crude treated with different levels of wax inhibitor were also considered. Multiple cycles of displacement and hot oiling were then modelled to evaluate the wax buildup over time and the ability of topside pumps to provide sufficient flowrate to displace production fluid. Modelling in commercial software packages was performed in parallel with modelling of the system using correlations found in literature. The modelling of uninhibited dead crude showed strong non-Newtonian behavior when under flow through pipe without insulation as the fluid rapidly cooled below the wax appearance temperature. The uninhibited fluid also showed gelling behavior when cooling down from hot oiling, and was therefore not considered a feasible option. Crude dosed with a wax inhibitor showed a reduced pour point and viscosity, which also reduced gelling effects. The fluid was able to be circulated by the pumps at a sufficient flowrate to remove production fluid from the pipe but also exhibited significant wax deposition due to rapid temperature changes when entering uninsulated pipe. The resulting wax deposit poses the risk of interfering with pipe integrity assessment. Further work is now ongoing to identify more effective wax inhibitors and alternative methods of assessing pipeline integrity. This study offers further insights into wax deposition and non-Newtonian fluid modelling in both insulated and uninsulated flowlines as well as the effectiveness of modelling non-Newtonian frictional pressure drop and wax deposition in parallel with commercial software packages to develop more effective models.
Improving Safety, Risk Mitigation, and Efficiency for Installation, Repair, Maintenance, and Decommissioning of Subsea Equipment
Authors: Nordhauser Alyssa , Knudsen Jay , Shannon Michael , Hartwig Christian
Published: April 2024

Working offshore in maritime operations is dangerous, making it key to mitigate risks as much as possible. The environment is extreme and challenging - even small changes to current operations and equipment can significantly improve safety and lower can the probability of a negative outcome should an incident occur. This paper will discuss some of those dangers as well as how utilizing a reaction washer (RW) for hydraulic bolting operations is a practical and safer alternative to using bolting tools with reaction arms.

Diving in general is inherently risky as humans enter a world for which they are neither designed, nor naturally equipped to be in. Commercial diving (offshore, inland, or industrial facility) is an especially hazardous job that requires working long hours in dangerous and unpredictable conditions while donning bulky and expensive equipment. Both equipment and human divers may be subject to water temperatures that range from 80°F to sub-zero. Divers and ROV's are exposed to a variety of marine hazards like low visibility, plant life, marine animals, current or sea state. Concerning issues for divers specifically include the risk of drowning, respiratory and circulatory complications, and hypothermia. Often the water at these depths is murky, sometimes with a only foot or two of visibility (or none at all), making it difficult to be fully aware of one's surroundings (pipelines, structures, hoses, tools, and other equipment). This can result in a diver hitting their back, head, or equipment on any number of subsea obstructions. When a diver surfaces too quickly they risk Decompression Sickness (DCS or The Bends), which is one of the most critical and potentially deadly risks of working underwater.

ROV's are another option for subsea bolting operations. They are subject to many of the risks mentioned above for human divers, and face hazards of their own. ROV's are expensive and extremely complicated pieces of equipment requiring lots of support and maintenance for their many systems (hydraulic, electrical, computer, sonar, navigation, lights, and cameras). There is a high rate of maintenance time per hour of operation, and repairs or replacement can be very costly. A key piece of equipment, the arm-like manipulator (there are typically two per ROV), ranges from $500,000 to $650,000 (each), in addition to the high cost of the ROV itself.
Using Ecological Risk Assessment to Assess EMF Impacts to Marine Life From offshore Wind Infrastructure
Authors: Preziosi D. , Dawson D. , Flanary C. , Raghukumar K. , Eikenbary S. , Hull D. , Schultz C.
Published: April 2024

Offshore wind is a focal point of U.S. strategy for renewable energy, with several projects along the East, West and Gulf coasts slated to achieve a federal wind target of 30 gigawatts by 2030. Offshore wind projects will generate and transmit renewable energy, and certain components (e.g., buried cables) will generate both electric and magnetic fields, collectively referred to as EMF. Research has demonstrated that marine species across various taxa interact with EMF produced from both natural and anthropogenic sources. For species known to be sensitive to EMF (including certain finfish, the elasmobranch group, and benthic invertebrates), interaction with anthropogenically generated EMF may influence the detection of electric and magnetic fields used in foraging, avoidance, mate selection and migration. To evaluate the potential for impacts, we apply the standard framework for ecological risk assessment (ERA). This framework offers a systematic approach and appropriate context for assessing exposure and potential hazards to characterize risk. A conceptual model is used to describe sensitive species with the greatest potential for exposure, and the spatial and temporal scales of exposure. To estimate exposure, we use both open-source (EMF Python package) and commercially available software (COMSOL Multiphysics®) to mathematically model applicable direct current and alternating current EMF generated by various components (e.g., inter-array cables, export cables). Field strengths decline with distance from conductors but vary with parameters such as voltage, amperage, conductor diameter, and shielding. For each component, we then take predicted field strengths at different distances and compare them to effect screening levels for marine life. Application of the ERA framework dramatically improves the information used to inform preconstruction impact assessment for offshore wind. The method provides quantitative estimates of risk and allows for the comparison of how different management options, such as different burial depths and spacing of components, influence risks. An additional advantage of the approach is that it can be used to identify important areas where more information is needed, such as the need to better define the spatial and temporal scale of populations relevant to individual offshore wind projects and cumulative projects. We recommend the ERA framework be adopted more widely as a systematic process for capturing and integrating context-dependent information necessary for characterizing EMF risk for marine life.
Hydrate Non-Plugging Evaluation of Crude Oils in Varying Shear Environments
Authors: Greener O. V. , Castrejon-Miranda R. , Delgado-Linares J. , Koh C. , Palermo T. , Fidel-Dufour A. , Mateen K. , Afra S. , Turner D. , Johnston B. , Teixeira A. , Valim L.
Published: April 2024

Establishment of the tendency of crude oils to disperse hydrates formed during slurry transport is of foremost importance when designing and implementing mitigation strategies in the field. In this work, high pressure quantitative rheological measurements were compared with visual qualitative agglomeration rocking cell results to quantify the impact of shear on the non-plugging performance of a crude oil. Shear rate in the rocking cell apparatus was modeled using computational fluid dynamics simulations and allowed acquired rocking cell data to be compared to rheological data on the basis of shear rate. Rocking cell visual agglomeration data were found to agree qualitatively with measured rheology results using this crude oil. It was found that increasing shear rate in rheology experiments lowered the final value of relative viscosity of the slurry. Contact angle and film growth measurements allowed for an improved mechanistic agglomeration understanding to be developed in this work. The use of variable shear comparisons provide important insight into not only the capability of oils to transport hydrates naturally, but also the range of applicability of data acquired using various benchtop experimental equipment.
Considerations with Respect to the Technology and Economics of Nodule Offloading from a Deep-Sea Mining Production Vessel to a Transport Vessel in the Open Ocean, and Transportation to a Port for Offloading
Authors: Wodehouse Jim , Halkyard John , Anderson Michael Rae
Published: April 2024

Application of Proven Technology to Nodule Offloading and Transport from a Deep-Sea Mining Production Vessel to a Transport Vessel in the Open Ocean, and the Evaluation of the Most Cost-Effective Overall Project Configuration for Typical Commercial Deep Sea Mining Scenarios.
Anchor Project: Best Practices and Lessons from Delivering the Offshore Installation Scope
Authors: Reiners, P. E. J. M. , Cheatham B. , Dampman B. A , Gaudet K. , Nakhle F.
Published: April 2024

The Anchor floating production unit (FPU) is a Chevron Gulf of Mexico (GOM) facility located in about 5,000 ft. of water with a nameplate capacity of 75,000 bopd and 28 mmscfd with future expansion capability. The Anchor development plan consists of seven high pressure 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 touch on best practices and learnings from FPU transportation and installation, hook-up and commissioning (HUC), as well as subsea flowlines, export pipelines and subsea equipment installations.

This paper will explore the keys pillars that enabled the successful execution of the offshore scope. These include a carefully established contracting strategy, detailed multifunctional planning and management of interfaces, high performance focus in design and execution, disciplined scope and progress management and development of a strong project and safety culture.

The Anchor offshore installation campaigns commenced in the second quarter of 2021 with all major work scopes completed by end of 2023. HUC will be completed by the first half of 2024. By establishing broad installation windows, the project was able to adjust execution campaigns for optimal weather conditions and vessel availability. Additionally, this flexibility enabled the project to mitigate impacts caused by the COVID-19 global pandemic. The contracting strategy and focus on core contractor competencies further reduced potential risks.

Innovative solutions and actions taken to address the many challenges of executing a major capital project (MCP) that includes new technology during a global pandemic and market downturn will be discussed.

For clarity, the following terms are used throughout this paper. High Pressure High Temperature (HPHT) refers to equipment rated to pressures greater than 15,000 psi and/or temperatures equal to or greater than 350°F. Anchor is a high pressure project under the HPHT category. 20K refers to the Anchor project's technology development and qualification program.
Monopile Penetration Through Scour Protection – Full Scale Testing and Discrete Element Analysis
Authors: Barbuntoiu T. , Thijssen R.
Published: April 2024

There is no established methodology available in literature to assess the penetration resistance of (Mono)Piles through pre-laid scour protection, as concluded by Barbuntoiu (2021). Due to the lack of available literature, standard practices or industry guidelines on this topic, the authors performed in-house research on the subject. This paper deals with full scale testing performed to investigate the load-penetration behavior of armor rock. Tests comprised penetration of a steel pile section of a monopile into armor rock of two different gradings, placed on a sand bed in a 20 ft container. A DEM model with an equivalent setup was built and calibrated against the experimental test results and subsequently used to model a full size monopile case. Insight into the variability of penetration resistance was acquired by conducting multiple tests during the experimental and numerical modelling phases. Next to estimating self-weight penetration, knowing the penetration resistance over depth relation for a given scour protection layer provides an understanding of the penetration behavior of the pile at the transition zone between scour protection and seabed (i.e. potential for punch-through) and answers the question about necessity to use a piling hammer to penetrate the scour protection.
Non-Intrusive Separator Level Measurement – Towards the First Offshore Pilot
Authors: Gorski D. , Lieske U. , Neubeck R. , Bindingsbø A. U.
Published: April 2024

Non-intrusive measurement of level in process vessels such as oil and gas production separators offers opportunities to significantly decrease installation and maintenance costs as well as to increase personnel safety and instrument reliability. This has a positive effect on process efficiency and reduces emissions. Provided the measurement technique can offer insights into levels of solids, emulsion, and foam layers, non-intrusive level measurement could potentially become an enabling technology for additional extensions of asset lifetime. This is because a non-intrusive profiler would be a game-changer for process and production control on assets in operation where retrofitting such an instrument is today prohibitively expensive due to its intrusive character.

A novel non-intrusive level measurement technique that utilizes Guided Elastic Waves (GEW) has shown very promising results in laboratory and pilot scale. This paper describes its development, starting with idea and leading towards the first full-scale trial on an offshore installation. The last experimental results, obtained towards a TRL4 qualification with an operator company, show excellent level detection of solids and liquid levels with virtually no error. Induced liquid flow had no influence on the measurement results and the signal did not drift when the system was left running for a month.

In addition to describing the experimental results and the technology qualification process, this paper also provides some reflections on the prioritization with respect to development and testing in the different stages of the qualification process. The prioritization is based on risk and cost benefit evaluation.
Enhancing Offshore Installation Decision-Making Through the Integrated Application of Vessel Motion Based Criteria (VMBC) Methodology and Digital Tools
Authors: Gueret R. , Cooper D. , Moen J. M. , Nilsen-Aas C. , Sjøvaag H. S.
Published: April 2024

Optimized decision-making processes for offshore installation operations is paramount to ensure both safety and efficiency, dependent upon reliable evaluations of prevailing environmental conditions. Traditionally, operational determinations have depended on the consideration of significant wave height (Hs) and wave period (Tp) limits. However, a shift in this domain has been challenged by Subsea 7 through the inventive "Vessel Motion Based Criteria, VMBC" methodology.

The VMBC methodology encompasses two central tasks, jointly contributing to an integrated decision support structure:

First and foremost, the identification of variables steering installation activities, such as the dynamic behavior of flexible risers, optimal gooseneck landing speeds, and critical crane top tension, forms the bedrock. Then by establishing correlations between these key parameters and the vessel's motion at predefined points of interest, termed as control variables, a well-defined threshold for maximum allowable vessel motions is derived. This threshold, represented through extreme value statistical parameters and indicative of operational limits, forms the cornerstone of safe and efficient operation planning.

The second is the development of a digital tool mirroring real offshore processes, ensuring that insights derived are directly applicable to operational scenarios. The digital tool streamlines the data collection process of the latest weather forecast and sensor data and automates the calculation of activity feasibility. This is done by utilizing the potential of metocean forecast reports, encompassing directional wave spectra and the vessel's response amplitude operators (RAOs), to numerically assess probable motions many days in advance. This empowers offshore stakeholders to plan and assess upcoming activities based on accurate prediction of vessel response with the objective of reduced waiting on weather without compromising safety.

This paper introduces an enriched understanding of how the VMBC method is used in real life operations. A methodology is presented that integrates applied theory with sensor technology and cutting-edge digital tools to deliver a more refined perspective on offshore operation planning and control. The paper culminates in a use case presentation, spotlighting the VMBC method in action and opportunities for more accurate determination of operability. This practical illustration shows the method's tangible benefits and the value of its integration with digital tools.
Extending the Production Life and Improving the Recovery by Utilizing ICD’s in Horizontal Well Completion, Success Story of Mumbai Offshore Field, India
Authors: Kaulaskar Mahadev , Thapliyal Anil , Biswas Soumyabrata , Choudhary Suparana , Ram Binay , Pramanik Koyel , Nagaonkar Ajinkya , Mishra Shubhra , Guguloth Vidya , Saroj Shivank
Published: April 2024

Better sweep efficiency and larger drainage area in horizontal well design improves the well production performance. As a matter of fact, it is widely used in water drive reservoirs and tight formations. Horizontal well completion, in combination with mechanical water control design, influences the performance in a much better way. Water production is habitually a significant apprehension during the production life of a well producing from the heterogeneous carbonate bottom water drive reservoir with high permeability. Continuous increase in water production impacts the operating costs, economics of production and early relocation/abandonment. This paper focuses on success story of improving oil production from an offshore carbonate reservoir field through completion of inflow control devices (ICD's) with swell packers in horizontal wells. The adoption of this technology resulted in delayed/reduced water production and improved sustainability of oil rate and higher cumulative oil production.

The ICD is a throttling device that creates additional pressure differential when the reservoir fluids flow into the wellbore through this device. It is able to control drawdown to eliminate the water coning caused by reservoir heterogeneity and the heel-toe effect, so that the horizontal well liquid profile is balanced and the oil-water interface is uniformly raised. Selection of pertinent well completion system requires understanding of historical production performance with their completion details, possible sources of early water production, available methods for reduction of water production and efficacy of adopted measures for water control in the field.

This case study brings about the impact of ICD completion used in horizontal wells in the water drive reservoir wherein improved well performance; delayed water cut and additional oil production than the slotted liner completion has been witnessed.

Selecting the precise and appropriate completion method directly determines the future development and production options with improvement in oil recovery. This extends the well production life span with low investment to achieve more production. And thus, ICD's in horizontal well completion plays a significant role in maximising the economic benefits from field development strategies.
Holistic Subsea Chemical Delivery Design and Management
Authors: Gao Shawn
Published: April 2024

Subsea development projects face significant flow assurance and production chemistry challenges that require the application of chemicals subsea or downhole. The application of these chemicals via umbilical/downhole capillary string requires stringent qualifications prior to deployment to avoid system failure due to blockage or corrosion resulting in loss of integrity. It also requires properly designed chemical delivery system to ensure proper dosages and uptime can be steadily/reliably delivered for the chemicals to be effective, including proper storage volume, pump size/turndown, metering, chemical injection valves, etc.

The paper is to share the best practice of having an end-to-end view on properly managing subsea chemical delivery, including what can and have gone wrong if not followed. For example, chemical/material compatibility is a key qualification requirement for subsea chemical delivery. However, when requested for demonstrating compatibility with the chemical injection system, each chemical vendor typically have their own internal "list of materials". It hasn't been fully recognized that the actual list of materials that the chemical can encounter throughout the entire chemical injection flow path from transportation to tanks, pumps, injection lines, and mandrels/valves, can be way more extensive. Getting one compatibility wrong, it will become the Achilles’ heel and compromise the entire injection system and render the chemical treatment ineffective. Therefore, designing the chemical delivery system and qualifying subsea chemicals with an end-to-end view is crucial to the success of chemical treatment programs and oil/gas production.
Decarbonization in Offshore Services: A Study on Efficiency and Emissions Reduction
Authors: Passos R. B. , de Aguiar R. B.
Published: April 2024

This study provides a comprehensive review of recent discussions on carbon equivalent emission reduction alternatives, emphasizing the importance of efficiency in Offshore Supply Vessels (OSVs). It introduces relevant indicators tailored for assessing ship efficiency in the specific context of subsea installations offshore. The examination of new technologies spans from enhanced navigation devices to minimizing fuel consumption during dynamic positioning. Safety considerations, crucial for OSVs operating near other structures, are addressed alongside the efficiency analysis.

To gauge the effectiveness of these measures, the study conducts a comparative analysis of fuel consumption indicators across the fleet of the major Brazilian oil company, accounting for operational nuances and propulsion capabilities. In the realm of subsea installation services, the engineering challenge lies in balancing propulsion power to ensure vessels can maintain position even in worst-case failure scenarios.

Given the diverse activities of the offshore supply fleet, involving tasks such as human diving, ROV missions, tug support, and subsea equipment handling, the study introduces efficiency indicators based on a comprehensive database analysis. The focus shifts to comparing efficiency across different vessels and their respective activities, highlighting the importance of strategic vessel selection to operate at each site. This extends beyond propulsion systems, considering the vessel's effectiveness in varied sea states. Inherently different from traditional cargo transporters, OSVs play a crucial role in attaining emission reduction objectives.

The study draws on the analysis vessels currently operational in Brazilian offshore, equipped with ROV onboard. By evaluating key indicators for optimal efficiency, the research contributes valuable insights to emission reduction initiatives, aligning with the overarching goal of steering towards a net-zero trajectory.
Where Deep Space Meets the Deep Ocean – Exploring the Extreme Environments of Space and Deepwater
Authors: Zeid Hosam Abu , Elshahawi Hani
Published: April 2024

Exploration and exploitation of deep space and the deep oceans has powered much technological progress. With their extreme operating environments, these two remote and hostile domains have posed many challenges and has produced many solutions. The study of each of these extreme environments has significantly enhanced our understanding of the other, and the technologies that enable prospecting and extracting resources in one environment can often be adapted for use in the other. For both deep space and deep ocean, there is much to be learned from other sectors such as the medical industry as well. For example, medical imaging technologies such as magnetic resonance imaging and computed tomography scans resemble the non-destructive testing techniques used in space and deepwater energy business. Similarly, robotic surgery is analogous to Mars Rovers and remotely operated vehicles used under water, and remote patient monitoring for more personalized and effective healthcare is comparable to the data analytics and machine learning used for proactive health monitoring in deep space and deep ocean. Digital transformation has been impacting all industries, and deep space and deep ocean are no exception. Digital transformation has three primary foundations: data-digital information; analytics-using the data to make better decisions, faster; and connectivity-data exchange between humans, machines, and devices. Various technologies enable and cut across these domains including sensors, cloud computing, edge analytics, automation and robotics, 3D printing, augmented reality, and artificial intelligence all underlain and enabled by accessible, affordable, and reliable energy. The objective of this paper is to explore the potential of such technologies at intersections between deep space and deep ocean. It will also document how the deep space and deep oceans hey have learned from each and have also leveraged advances in other sectors, principally medical and healthcare.