bluuebunny/crossref_metadata_2025 huggingface dataset:
Bonga FPSO: Asset Management Excellence
Authors: Agala B. F. , Jonathan A. R. , Ofoedu A. , Ayodeji A. , Okon U. , Afuba P.
Published: April 2024

Bonga field is located 120 km South-West of Warri, in the Southern Niger Delta of Nigeria, at water depth of 3300 ft. The field was discovered in 1993 and achieved first oil in November 2005 as the first deepwater development in the Gulf of Guinea. It was developed with subsea wells, production manifolds and water injection terminals connected via subsea flowlines and risers to a Floating Production, Storage and Offloading (FPSO) facility called the Bonga FPSO.

Bonga FPSO consists of oil and gas processing and export facilities, water injection facilities, oil storage facilities, and utility systems that support production operations and personnel onboard the vessel. Over a 17-year period, the FPSO has achieved cumulative oil production of 1.0 billion barrels, 815 Bscf of gas export and 1.5 billion barrels of water injected through a total 39 oil producer and 36 water injector wells.

This performance was delivered by disciplined implementation of a structured Asset Management framework with focus on work processes that deliver performance, a management system that define how the asset operates, and clear definition of the assets longer-term strategic intent, vision, value levers, and the choices required to deliver maximum business value.

Through the asset management framework, the FPSO has consistently delivered top quartile performance in safety and environment, production availability, asset integrity, equipment reliability, and turn around excellence. In 2022 the asset delivered a turnaround maintenance 8 days ahead of schedule with zero safety incident at a lower cost. In February 2023, Bonga achieved cumulative export of 1 billion barrels of oil and 815 Bscf of gas, and cumulative water injection of 1.5 billion barrels. The asset is on track to deliver a production availability greater 95% and a carbon emission reduction of 0.3million tCO2e through reliability improvements on gas compression system.

This paper presents the Asset Management excellence philosophy of Bonga FPSO

Ensure Safe Production: A structured process that enables cost-effective operation within defined operating envelopes. Manage Threats and Opportunities: A process that enables identification, prioritization and mitigation of threats and realization of opportunities. Perform Maintenance Execution and Manage Equipment care: Two frameworks for maintaining and improving the integrity, availability, and reliability of the asset through optimized maintenance strategies. Perform Turnaround: A structured framework to effectively plan, schedule, control and execute turnarounds to improve operational excellence and asset integrity.

This paper is one of a series of Bonga themed papers proposed for OTC 2024.
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

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

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

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

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 <1), nucleation and crystal growth exhibited a more uniform distribution from the pipeline wall. Conversely, for faster kinetics (Damköhler number >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

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

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

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

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.
De-Risking Downhole Disconnection Tools for Open Hole Intelligent Completion in Deepwater Wells
Authors: Schnitzler E. , da Silva Jr. M. F. , Oliveira Jr. A. F. M. , de Oliveira F. S. , Roman R. S.
Published: April 2024

This paper presents how Petrobras, in collaboration with suppliers and other operators, proceeded with a qualification and deployment plan for one of the new technologies recently introduced in its pre-salt wells. It covers the new downhole disconnection tools for control lines used in intelligent completion systems deployed in open hole, also known as WDT – Wet Disconnect Tool. Downhole disconnection systems allow connecting and disconnecting the tubing and control lines, hydraulic and electric, between the upper and lower completion. This equipment is frequently used when the ICVs are deployed in open hole, as applied in the latest pre-salt projects in Brazil.

However, a successful performance of these tools may be severely impacted by downhole conditions and the intrinsic challenges in deepwater wells. High mechanical loads, pressure and temperature variations, aggressive wellbore fluids and the presence of debris are just some of the concerns. Therefore, the operator has set a robust qualification plan to de-risk the introduction of this technology in its offshore fields.

In strong collaboration with the suppliers, the possible weak points and risks were identified and addressed in the qualification plan. This development was also guided by reliability targets for the final systems, based on reliability tests at component, sub-system and system levels.

One of the main concerns was to establish a successful connection in the well between the two parts of the tool. Despite all the efforts to clean the wells before completion deployment, the presence of debris is always a risk, and some debris tolerance need to be considered. A representative mixture of debris was defined for the connection and disconnection tests, mimicking wells conditions as much as possible.

The overall development and qualification of the tools was successfully finished, after several changes in the original designs. In the end, the tools showed good debris tolerance and positive expectations in terms of the performance in downhole conditions. The trial wells, where the tools were deployed already connected (single trip), faced no issues related to the new tool. Dual trip installations are expected to happen shortly.

The innovative use of downhole disconnect tools in deepwater wells opens several opportunities for projects that benefit from the use of intelligent completion. Improving these tools robustness and reliability helps building the necessary confidence for this kind of application. Future opportunities of incorporating downhole fiber optics sensing in the lower completion and electrically actuated valves also benefit from this experience.
Subsea Hydrogen Long Duration Energy Storage
Authors: Labes A. , Myhre T.
Published: April 2024

Nations around the world are progressing in adding renewable sources of energy to their grid as an attempt to meet CO2 emissions targets and provide power to increasing demand. The higher portion of intermittent renewables like solar and wind to the electrical grids have created a need for technologies that can not only provide resilience to the grids, but also have low greenhouse gas footprint. Long Duration Energy Storage (LDES) technologies are currently under development to fill this gap. Of the many LDES technologies, Hydrogen based systems is proposed as viable energy storage system for very long periods, including interseason periods, where hydrogen is stored in salt caverns.

In this paper we describe an alternative LDES system based on hydrogen, where hydrogen is stored in pressure vessel at the seabed. Subsea storage provides a safe location for a large mass of hydrogen to be stored at a stable temperature environment, while requiring a reduced footprint on land, and providing geographic flexibility.

The subsea hydrogen LDES system can fit a space where power can be provided for 10-100 hours, or more depending on the application, and by so, performing an economical mean to integrate renewables to a grid, or to enable a full renewable based grid to be sustained in isolated islands.
Macro-Models for Anchor and Chain-Soil Interaction in Floating Offshore Wind Analyses
Authors: Jostad H. P. , Rui S. , Zhou Z. , Wang Y. , Huynh D. V. K.
Published: April 2024

A numerical formulation is introduced for modelling the dynamic interaction between the mooring line (chain) and the soil, extending to the connection point at the anchor (pad-eye) in a fully integrated analysis of an offshore wind turbine generator, floating support structure and mooring system including the anchors. The anchors and the segments of the mooring line in contact with the soil are modelled by macro-models. The macro-models describe the coupled non-linear relationship between incremental displacements and the resultant soil reaction forces at each node along the mooring line in contact with the soil and at the pad-eye in a 3-dimensional space. The calibration of the input for two distinct types of anchors - suction caisson anchors and fluke anchors in clays, is presented. By implementing these macro-models into a tool for simulating the dynamic behavior of the floating offshore wind turbine, the design process of the anchors can be faster and more accurate. Importantly, a holistic approach to the mooring system design, including the interaction with the soil, has the potential to optimize the design and reduce the costs. It also enables the prediction of the potential development of complex mechanisms such as seabed trenches during repeated motion of the mooring line in contact with the soil. An example is briefly presented to demonstrate the application of this integrated analysis of floating offshore wind turbines, emphasizing the additional input required.
Risk-Based Inspections Using Digital Twins for Hulls and Structures of Floating Assets
Authors: Stensrud E. , Bjørdalsbakke H. O. , Hamre G. , Raeissi B. , Richardsen T. , Torstensen Are , McKay D.
Published: April 2024

This paper presents a research and development project undertaken by DNV to develop digital twins of hull compartments on floating assets, wherein inspection findings are collected and documented for analysis and reuse. This process aims to drive increased efficiency in future inspections. Data gathering is performed by intelligent autonomous drones capable of self-navigation in structurally complex compartments. These are coupled with AI-driven algorithms that detect and identify findings such as cracks, corrosion, and deformations. The project serves a dual purpose: firstly, to reduce the need for manned entry into hull compartments, and secondly, to enhance the efficiency of planning and execution of future inspections. This is achieved by ensuring known findings are identified, mapped in the digital twin, and can be easily located and reassessed.

The drones are equipped to perform both close and general visual inspections, although further development in lighting is necessary to support general visual inspections of surfaces in large hull compartments. The surveyor then reviews the inspection findings and identifies actual defects, which contributes to the continuous learning of the detection algorithm. Successful trials have been conducted with both free-flying and tethered drones.

Future development is planned to focus on improving automated inspection planning and visualization for monitoring compartment conditions. Additionally, enhancements are aimed at increasing the capability for anomaly detection, improving drone navigation in structurally complex spaces, and enhancing the capacity for data gathering while in motion.
Practical Qualitative and Quantitative Models in Carbon Capture Utilization and Storage Risk Assessment
Authors: Sneddon J. , Busby A. , Hurst S.
Published: April 2024

Carbon Capture Utilization and Storage (CCUS) has been recognized as a tool to aid the decarbonisation of carbon heavy industries, with the storage of CO2 in the subsurface over geological timescales being a key component in the CCUS process chain. Assessing and managing the risks involved in subsurface storage of CO2 is required so decisions can be made about the design, operation, monitoring and acceptability of potential projects. As with existing industrial activities, a number of approaches exist for assessing risk ranging from purely qualitative approaches through to quantitative approaches.

A structured, proportional risk assessment approach is proposed, aimed at identifying, analysing and evaluating the risk from a candidate subsurface store through a combination of qualitative and quantitative techniques to gain the most benefit. Development of a register of subsurface containment risks allows for the identification of scenarios of concern, which can be coupled with risk matrices to provide an estimation of the risk level together with its acceptability. More in depth qualitative techniques such as bowtie analysis encourage different disciplines to collaborate and enhance communication, both internally and externally, of the controls present for the most significant risks. The combination of bowties with a quantified, event tree-based model can allow for numerical determination of leakage probability and magnitude. Quantitative methods can therefore estimate insurance liabilities and allow comparison of options or with acceptance criteria. However, these assessments are underpinned by the quality of inputs. Given that the CCUS industry is still in its infancy, data surrounding event likelihoods and leak magnitudes, especially for geological leakage pathways, can have large amounts of associated uncertainty; this uncertainty must be taken into account when evaluated the overall acceptability of projects. Whilst both quantitative and qualitative methodologies for risk assessing subsurface CO2 storage have their advantages and disadvantages, it is when combined as part of a structured CCUS risk assessment approach that the most benefit is gained.
Enabling the Electrification of Offshore Activities – Co-Demonstration of Next-Generation Autonomous Offshore Power System and Resident, Uncrewed Mobile and Static Assets at PacWave Wave Energy Test Site
Authors: Hammagren E. , Lesemann A. R.
Published: April 2024

Oceans cover two-thirds of the earth's surface and form the world's biggest and best – yet largely untapped – battery. Ocean waves have more energy density than other renewables, including wind, solar, and biomass, and have the potential to supply 4x the world's annual energy consumption (Masterson, 2022; Zic, 2020). In addition to the impact wave energy can have on decarbonizing and diversifying the electric grid, it offers a significant value proposition in the emerging blue economy sector (LiVecchi et al, 2019). The blue economy consists of industries operating offshore, including shipping, oil and gas, defense and security, aquaculture, and research. These industries require bringing people and energy on site to perform daily work, but current energy costs in the blue economy are extremely high. The prevailing processes are complex, including shore dependencies and fuel transportation logistics. Few alternatives for reliable power generation exist, with the most prominent being high cost and high carbon emissions diesel generation. Because of this lack of affordable, reliable power, the trends of electrification, digitization, and automation that have led to substantial innovation and improvements in the terrestrial economy over the last two decades are slow to come to the blue economy.

An Autonomous Offshore Power System (AOPS) provides a cost-effective power solution for the blue economy. An integrated system consisting of power generation, energy storage, asset management, and data communications, an AOPS can transform how industries operate in the ocean today. They can enable autonomous, digital, longer-residency assets and drive lower cost, complexity, and carbon-intensity.

The U.S. Department of Energy-sponsored PacWave South test site, slated to open off the Oregon coast in 2024, provides a critical test facility for AOPS technologies. The focus of this paper is the process of designing and building a third-generation AOPS for testing at PacWave South, incorporating lessons learned from three previous design, build, and test cycles.
Marlim & Voador – XT Life Extension and Reuse
Authors: Soares R. F. , Fonseca M. M. Capella da , Palmieri I. , Diehl B. , Orlowski R. T. , Aguirre M. H. , Filho P. T. Diniz , Pereira R. M. , Gomes A. L. , Barros L. O. de , Bueno M. N.
Published: April 2024

The Marlim and Voador fields revitalization project aims to extend their production until 2048 through the deployment of two new FPSO units, combining the drilling of new wells with the utilization of aged wells. The project also includes the replacement of existing units, improving field efficiency, and reducing CO2 emissions.

This paper describes the methodology used for the XT life extension and reuse in the Marlim and Voador fields.

In the producing wells it was only possible to reuse the full clad XT, because the corrosion rates worsen significantly for future conditions, where wells with high CO2 contents will be interconnected to the FPSOs, contaminating the gas-lift of all wells. On the other hand, the XT of the water injector wells could be mostly reused, although the corrosivity of the water injected in the future is potentially more severe, due to the reinjection of produced water.

The analysis of technical reports showed that most of the XTs were approved for reuse, with valve integrity being the main reason for rejection. The reuse of XTs significantly contributed to the project’s Net Present Value (NPV) and resulted in the avoidance or postponement of approximately 48 ktons of CO2 emissions.
Well Construction Records and its contribution for Campos Basin Revitalization
Authors: Duccini L. E. A. , Petersen F. C. , Júnior A. C. R. , Marques M. , Miranda J. P.
Published: April 2024

In the Campos Basin, Petrobras discovered the first giant fields in the 1980's, which led to a technological development enabling worldwide deepwater production and later, the production of the Pre-salt fields. Additionally, the achievements in Marlim and Roncador fields have earned two OTC awards. Over the past 40 years, more than 14 billion barrels of hydrocarbons have been produced in the Basin, and it currently accounts for approximately 25% of Brazil's total production.

Despite its historical significance, the Campos Basin faces challenges related to declining production from mature fields, as many productions units and wells are reaching the end of their lifespan, requiring investments in infrastructure and exploration. However, the basin still holds significant untapped resources, providing opportunities for future development and growth, as the main Concession contracts have been extended beyond 2048.

New projects have been conceived and integrated into Campus Basin Revitalization Program (Marlim, Albacora and Barracuda), in which Petrobras plans to invest U$22 billion up to 2028. However, ensuring the viability of brownfields projects requires careful control over Capital Expenditures (CAPEX) and Operational Expenditures (OPEX), or the costs of well construction would impact deeply in the project benefits.

This paper provides an overview of the efforts made by well engineering regarding design, practices, and processes implemented in recent years to enhance performance in well construction, enable economically marginal projects, and add greater value to the projects in the Campos Basin.
Latest Industry Data and Flexible Pipe Integrity Management Lessons from the Sureflex JIP
Authors: MacLeod I. , Picksley J. , Birmingham M. , Moir A.
Published: April 2024

The 5th phase of the Sureflex Joint Industry Project (JIP) provides the latest data-driven industry guidance relating to unbonded flexible pipe population and damage / failure statistics, integrity management guidance and good practice. To maximise knowledge and experience sharing, the full deliverable report has been made freely available through an open industry publication. This paper shares the key findings of the JIP.

The JIP gathered data from the industry, with wide global member support from flexible pipe suppliers, operators, and regulators, and a wide range of non-member stakeholder organisations. The data is gathered, assessed, desensitised and presented to provide the best possible integrity management guidance to pipe users. The JIP also included a series of workshops: assessing vendor inspection, monitoring, and repair technologies; evaluating other key flexible pipe challenges, and sharing of operational experiences, with the key findings presented in the main JIP report. An ongoing network continues and expands the sharing of data and lessons learned.

Whilst flexible pipe technology may be considered as mature, being commercialised in the 1970s, there has been an almost 1/5th increase in the volume of pipes delivered in the latest five-year period. This indicates an increasing volume of use, and the JIP data demonstrates the pace of technology acceleration of design parameters, as users of the technology seek to stretch the operational envelope.

The manufacturers continue to perform product research, development and qualification to meet this demand, though this has not prevented the emergence of a limited number of new failure modes. Reported Leak and Damage rates have shown a decreasing trend over the last 20 years, however the incident rate for rarer Rupture events has increased for Riser applications since 2011. These rupture events have been attributed to a relatively small number of failure mechanisms in specific applications, some of which have emerged in the last 5 years.

Important developments of existing and new inspection and monitoring technologies have continued, though further work to improve the reliability, ease of deployment and usability is required. Knowledge and experience sharing of successes and failures is key to ensuring that appropriate and relevant guidance is maintained and made available to the wider industry.

Building on the knowledge shared through the preceding JIP phases dating back 25 years, this initiative has compiled and shared the most comprehensive industry dataset of unbonded flexible pipe supply experience, damage and failure data, and corresponding integrity management mitigations in the form of guidance and good practice.
Accelerating Offshore Windfarm Site Characterization Using Deep Learning
Authors: Di H. , Simoes V. , Zhao T. , Abubakar A.
Published: April 2024

Developing offshore wind farms requires effective mapping of shallow subsurface for turbine foundation design, construction, and monitoring, all of which face many challenges in especially field data conditioning, structure interpretation and modeling, and geotechnical property estimation. In this paper, we revisit these challenges from the perspective of pattern recognition and propose implementing deep learning (DL) into automating three essential tasks in windfarm site characterization, including (i) cone-penetration testing (CPT) data conditioning, (ii) ultra-high resolution (UHR) seismic horizon picking, and (iii) integrated geotechnical property estimation, which leads to an accelerated workflow for delivering reliable ground models in an offshore windfarm site of interest. Specifically, the CPT data conditioning aims at identifying outliers in CPT data and reconstructing missing segments via a 1D auto-encoder. The UHR seismic horizon picking aims at tracking key horizons in collected UHR seismic via a two-step supervised DL and building a horizon model that captures the primary structural patterns in the target area. The integrated geotechnical property estimation aims at integrating the reconstructed CPT logs, the UHR seismic images, and the horizon models into simultaneously estimating multiple geotechnical properties such as cone-tip resistance (RES) and friction ratio (FRR) via semi-supervised DL. As tested over the public Borssele dataset within the Dutch Offshore Windfarm Zone, the proposed DL-accelerated workflow successfully improves the quality of CPT data, picks multiple major horizons that reflect the complexities of shallow subsurface, and constructs the corresponding RES and FRR models that delineate the lateral variations in geotechnical across the Borssele area.
Life Cycle Costing Application in the Energy Sector – Technology Applications
Authors: Mattioli M. , Willmann E. , Østebø R. , Paulsen E. H.
Published: April 2024

This paper presents use cases of the ISO 15663:2021 standard for industry cost management and business value crea-tion. The standard contains requirements and guidance on how to implement and apply the life cycle costing methodology, to provide decision support for selection between alternative competing options. The objective of the paper is to show recent indus-try applications and how value can be created by application of life cycle costing in oil & gas, particularly focusing on new technology development and lower carbon energy solutions.

ISO 15663:2021 provides a framework for value optimization over the entire life of an asset. It promulgates a manage-ment methodology and application of life cycle costing across all life cycle phases. The purpose is to provide decision support for selecting between alternative options for relevant life cycle costing subject matters.

The life cycle costing applicability to new technology innovation that can replace conventional technology will specifically be addressed based on recent operator and supplier studies.

The use case concerning the deployment of subsea drones in subsea field development is presented. Subsea drone deployment is one of most challenging improvement for the oil and gas industries, being a game changer for the carbon footprint and cost reduction of operations. The ISO 15663:2021 has been applied in order to guide the decision maker throughout a proper selection of different competing options and enabling a fully representative life cycle cost analysis.

The paper also presents an example of use of life cycle costing to compare and evaluate differences in business performance, as well as opportunities, between conventional topsides and Subsea Chemical Storage and Injection System (SCSIS) for subsea wells. The methodology served as a comprehensive tool for comparing the life cycle cost of two alternative options.

Oil & Gas Operators as well as Contractors and Vendors are the main users of ISO 15663:2021. Besides the use cases presented in this paper, the ultimate goal of the authors is to demonstrate that by using a proper life cycle costing methodology, the decision making can be ultimately rigorous and coherent.