bluuebunny/crossref_metadata_2025 huggingface dataset:
Concept of Operations for Collaborative Human Robot Inspection and Intervention System in Challenging Underwater Environments
Authors: Kalyan Bharath , Chitre Mandar Anil
Published: April 2023

The onset of electrification and increasing penetration of renewable energy resources as well as prioritization for greater environmental, social and governance factors in the offshore energy sector will lead to the emergence of disruptive technologies. The offshore inspection, repair and maintenance (IRM) market was USD 8.93 billion in 2020 and is projected to grow to USD 18.04 billion by 2028 [1]. At present, remotely operated vehicles (ROVs) generally supported with large offshore support vessels (OSVs), have established themselves as indispensable for offshore IRM operations. Key emerging technologies such as 3D computer vision, mixed reality, digital twinning, and machine learning, coupled with significant advances in robotics, automation, sensors, and communication now make it possible to consider performing a range of undersea tasks using undersea vehicles without a tether, but under careful human supervision. It is now possible to radically redefine the meaning of the words "tethered system" through a hybrid approach by including virtual tethering via high frequency acoustic or optical communication at a short range, and with an extremely small optical fiber base station providing remote surface connectivity. By collaborating with an onshore/offshore remote human operator and a digital twin of the environment, battery-powered, tetherless hybrid underwater vehicles (HUVs) will be able to perform a range of tasks at a remote location that might otherwise require a conventional ROV and a support ship on site. The Collaborative Human Robot Inspection & Intervention System (CHRIIS) is aimed towards providing remote intelligent tetherless solutions to inspection and light intervention of offshore marine assets.
Digital Twin of a Generic Jack-Up Platform
Authors: Zhang Shanli , Zhang Chi , Santo Harrif , Cai Minbo , Si Michael Boon Ing , Cao Jixing , Quek Ser Tong
Published: April 2023

A development of physics-based digital twinning of a generic jack-up platform is presented in this paper. Due to lack of field measurement data, a generic large-scale jack-up model was designed, fabricated and tested in TCOMS ocean basin at 1:30 scale under different configurations, with the objective to provide high-quality datasets to validate the proposed digital twin methodologies. The framework and the performance of the digital twin are demonstrated using a realistic and representative basin-scale model as a proof-of-concept.

Fundamental to any physics-based digital twins is the establishment of numerical models capable of reproducing consistent behaviors and responses of the physical assets. For this digital twin development, a full order model (FOM) and a reduced order model (ROM) are established. In view of uncertainties associated with the physical asset and numerical modelling, e.g., foundation fixities, leg stiffness, leg-hull connection stiffness and hydrodynamic coefficients, model updating or system identification is performed using the ROM to identify the parameters with relatively large uncertainties. A mapping between the parameters and the associated responses of the FOM and the ROM is subsequently established.

After the model updating is completed with the identified parameters, good agreement in terms of the structural responses between the model test and numerical results can be achieved. Both the FOM and ROM are able to reproduce structural responses with good accuracy when compared to physical measurements. The ROM, being a linear structural model based on modal responses, is unable to account for larger non-linear effects due to spudcan fixities, if any. Nevertheless, the ROM is suitable for fatigue evaluation considering fast computational speed and validity of the piecewise linear constraints as assumed for the foundation. The FOM, being less computationally efficient, is suitable for strength evaluation and able to account for any non-linear structural behaviors. The results of boundary displacements from the global dynamic response analysis can be mapped to a detailed local joint model to derive the hotspots stress for a more accurate fatigue evaluation. The digital twin framework for fatigue and strength evaluations based on measured wave loading is demonstrated for a better structural integrity management.

As an emerging technology, digital twin will provide visibility of structural health condition to facilitate the transition from preventive to predictive and reliability-centered maintenance strategies. Although the digital twin framework presented in the paper makes use of a representative jack-up at model-scale, the proposed methodology can be potentially applied to full-scale operating jack-ups.
Junction Plate for High Pressure High Temperature System
Authors: Prakash Sunil , Semwal Pravesh , Strain Julie
Published: April 2023

Development of Ultra deepwater wells drilled to greater than 25,000 feet total depth in Gulf of Mexico (GoM) have led to the need for High Pressure (HP) systems. Existing MQC / Junction Plates were designed for maximum 15,000 PSI and needed to be updated to meet the 20,000 PSI system requirements. This paper documents the development of 20,000 PSI (20k) Multi-Quick Connect (MQC) / Junction Plate (J-Plate). This 20k MQC was updated in terms of material strength and qualified per API 17F.

All Pressure containing components and the internal MQC drive mechanism had to be updated and verified for a Design Pressure (DP) of 20,000 PSI. Design and Analysis iteration was performed to verify the structural integrity of the MQC/J-Plate under the design operational loads (both internal and external loads) with all couplers pressurized to a design pressure of 20,000 PSI and test pressure (TP) of 30,000 PSI pressure. In qualification (per API 17F) the MQC went through cycle testing for mated and unmated conditions under pressure, unbalanced pressure load, and hyperbaric testing of the MQC with environmental pressure of 4400 psig (equivalent to water depth 10,000 ft / 3,048 m).

Higher yield strength materials have been used for components as required to support the loading due to the high-pressure requirement. For higher stress (stress above allowable criteria in linear elastic stress analysis) areas, Elastic-Plastic stress analysis has been performed to check the structural integrity against the plastic collapse. The results of the analyses indicate that the MQC/J-Plate satisfies all the allowable criteria for the analyzed operational load cases. The coupler seal and body have been qualified by the vendor to required pressure and temperature cycles. A completely built MQC has been qualified with lines at 20,000 PSI design and 30,000 PSI test pressure per API 17F. Qualification tests were completed for the cycle testing (Balanced and Unbalanced) and hyperbaric pressure testing and successfully completed all cycle testing. In qualification, both mated and unmated conditions were performed with five cycles. MQC/J-Plate for High Pressure High Temperature (HPHT) has complied with all requirements of TRL 6.

The new 20k MQC allows for the ultra deepwater development utilizing the existing 15k reliable, field proven MQC system with minor modifications. New coupling bodies were developed to enable this high pressure MQC to work seamlessly across the production and control systems in the field.
Buzios: The Development of Well Construction in a Giant Pre-Salt Field
Authors: Sortica Emanuel Apoema , Percy Joseir Gandra , Goulart Leonardo Paiva , Oliveira Manuel Parcero
Published: April 2023

Búzios is the largest ultra-deep water oil field in the world, located on the Brazilian coast, in the pre-salt polygon. Its development has taken place at an accelerated pace, with more than 60 wells already drilled and 4 FPSO's operating by the end of 2022, and a forecast of 7 more installed up to 2026, and at least 80 more wells till 2030.

In this way, well configurations represent a great challenge, requiring technological and technical developments to allow high production flow and maintenance of integrity throughout the field's productive life, estimated in 30 years.

Several well configurations, whether in drilling or in completion, were applied with greater or lesser success, bringing objective results in the reduction of time in well construction: from 130 days at the beginning of development to durations of less than 80 days, reducing CAPEX and increasing the rate of return on investment.

This work aims to describe the various challenges faced in the design of well projects and construction, whether in drilling or completion, as well as how the geological characteristics of the field influenced the choices and methodologies adopted. In addition, demonstrate how the methodologies contributed to improve the quality of construction and linked to the reduction of time and costs.
An Advanced in-Line Sensing AI Framework for Enhanced Drilling Operations
Authors: Katterbauer Klemens , Al Shehri Abdallah
Published: April 2023

4th Industrial Revolution (4IR) technologies have assumed critical importance in the oil and gas industry, enabling data analysis and automation at unprecedented levels. Formation evaluation and reservoir monitoring are crucial areas for optimizing reservoir production, maximizing sweep efficiency and characterizing the reservoirs. Automation, robotics and artificial intelligence (AI) have led to tremendous transformations in these areas. From AI inspired well logging data interpretation to real-time reservoir monitoring, technologies have led to cost savings, increase in efficiencies and infrastructure centralization. In this work we provide an overview of how autoregressive deep learning methodologies can lead to major advances in the field of formation evaluation and reservoir characterization, providing a comprehensive overview of the technologies developed and utilized in this domain. Furthermore, we provide a future outlook for smart technologies in formation evaluation, and how these sensor-derived data can be integrated. This also describes the challenges ahead. Future developments will experience a growing penetration of 4IR technology for enhancing formation evaluation in subsurface reservoirs.
Scraping Assessment of Offshore Marine Risers
Authors: Alnutifat Shadid Ayedh , Alfosail Feras Khalid , Saleem Qasim , Alshammari Abdulrahman Saleh , Al khoufi Mohammad Salem , Harbi Mousa Rashed
Published: April 2023

The engineering assessment in this paper provides the recommendations for the minimum wall thickness selection of marine riser pipeline and their ability to allow the passage of in-line instrument scraper. The assessment was conducted considering two criteria: First, the minimum wall thickness for riser is evaluated against the minimum bore required by in-line instrument scraper provided by several service contractors for in-line inspection. Second, the riser minimum wall thickness is benchmarked with the minimum acceptable wall thickness specified by DNVOS-F101 [1] and Saudi Aramco engineering standard for submarine pipeline design.

The outcome of this analysis is the following recommendation:

The minimum wall thickness selected for riser pipeline diameters less than 8″ shall not be less than the values tabulated in Table 1 for each service.

These values ensure that adequate protection measures are considered during the design of pipeline which is in-line with the requirement of DNV-OS-F101. In addition, the outcome of the assessment results into a collective projected cost avoidance of $ 0.94M per meter of pipeline and reduces carbon foot print.
Unsteady-State Mechanical Formation Damage Modeling in Pressure-Sensitive Oil Reservoirs Near No-Flow Boundaries Using a Coupled-Integro-Differential-Perturbation Method
Authors: Fernandes Fernando Bastos , Braga Arthur Martins Barbosa , Gandra Percy Joseir , Cláudio Soares Antônio
Published: April 2023

Identification of no-flow zones and mechanical formation damage management are essential for a successful exploratory and production campaign during the development of an oil field. This work develops a new unsteady-state two-dimensional (2-D) integro-differential solution for permeability loss monitoring in a well near an infinite sealing fault. The model presented in this study allows solving the nonlinear hydraulic diffusivity equation (NHDE) with the oil source term. Based on image method (IM), the pressure field for the constant permeability solution is given by the sum of two exponential integral functions Ei(tD). However, this solution does not consider the nonlinear effect caused by pressure-sensitive permeability loss. A new deviation factor ξ(p) is derived and coupled to an asymptotic first-order series expansion to deal with this phenomenon. The model also allows for evaluating the oil flow rate influence on the permeability loss during the well-reservoir production curve. Sensitivity analysis investigates the parameters that highly influence the diffusivity deviation factor. Pressure and permeability input data were obtained through a uni-axial test performed in two sandstone layers of the same reservoir rock in an offshore field in Brazil. The analytical solution addressed in this paper was calibrated by a porous media oil flow simulator named IMEX®, broadly used in reservoir engineering works, and the results were accurate. The results present the instantaneous permeability decay effect by a deviation compared to the linear solution in a semi-log plot. The main advantages of the proposed solution are the accuracy, availability of a comprehensive table of the GFs, ease of implementation, and computational cost savings. It constitutes a valuable and attractive mathematical tool to calibrate new models and support well-reservoir performance management.
Vito Project Overview
Authors: Shallenberger Kurt Douglas , Fresquez Stacy Marie
Published: April 2023

In 2009, the Vito field was discovered in more than 4,000 ft of water approximately 150 miles offshore from New Orleans, Louisiana. The project produces from reservoirs nearly 30,000 feet below sea level. This paper introduces the challenges of the multidiscipline project from a project management perspective and to compliment and introduce the several other Vito Floating Production System (FPS) papers submitted to OTC 2023 which are listed in the references of this papar.

The original Vito project execution strategy was to replicate the mega-project of Appomattox. As the industry and market began to change in 2015, the project faced significant financial hurdles, and the project team decided to refresh the design concept to reduce cost and simplify. The new design included a smaller FPS, simplified operating model, and simplified subsea equipment. This allowed the project to open the contracting strategy to include more options including different fabrication sites, smaller offshore installation vessels, and include more vendor options in various disciplines.

The Vito host, subsea system, and export were redesigned with the mindset of "simpler = safer = cost competitive". The host was radically reduced and limited to a 10,000 st single deck lift enabling simplified integration and pre-commissioning at the ground level to optimize work pace. The mooring system was streamlined to remove on-vessel winching equipment and storage, simplifying the hull and utilizing common anchor handler vessels for host installation. A simplified Subsea Umbilical Riser and Flowline (SURF) design was competitively scoped by focusing on minimum amount of equipment to safely gather and transport the fluids and minimum amount of equipment to manage flow assurance risks. The export pipelines leveraged industry capabilities to simplify the design and contracting approach. The simplified minimum technical scope for the topsides and subsea reduced operations personnel needed offshore and upskilling the operations staff enabled a simplified overall design concept.

The world is dynamic and when changes are extreme, mega-projects must be reworked and mobilized for the new environment. Vito project is a story of change, simplification, and adaptation.
The Effects of Wind, Speed and Ice Pressure on PC3 Module Carriers During Winter Northern Sea Route Transits
Authors: Adkins Philip Jeffrey , Van Lievenoogen Rinse Adrianus
Published: April 2023

Two historical voyages were completed in December 2021 and January 2022 over the Northern Sea Route (NSR) in a westerly direction. A lack of accurate real time data regarding ice conditions and the influence of changing meteorological conditions severely complicated voyage planning.

Normal voyage planning for the Northern Sea Route is based on historical satellite data. The objective is to extrapolate possible ice conditions throughout the planned route. This historical data has not been taken into account changes in wind, current and relative ice pressure. In addition, the effect of wind drag on the "sail area" of modules being transported has a significant influence on the application of the power necessary to penetrate ice at the speed and fuel consumption calculations stipulated by the Vessels’ design.

The safe transit of the Northern Sea Route from the beginning of December to the end of March cannot be accurately predicted by using the historical data available today. This significantly increases the risk factors considered not only in pre-voyage planning but throughout the voyage itself. The application of the current regulatory regime requirements to navigate via the Northern Sea Route during the December-March period by no means eliminates the possibility of vessels becoming beset by ice.

Close communication with Rosatomflot prior to entering the Northern Sea Route is a necessity in order to appraise the ice conditions in higher risk areas as well as to optimized route planning. Furthermore, operational experience during periods of nuclear icebreaker support is critical to maintain safe progress on the Northern Sea Route.

This Paper will address these challenges, as well as attempt to quantify: The effect on wind pressure and wind direction on icebreaking capabilitiesThe effects of wind speed and direction on ice pressure relative to coastal geography.The effects of changing ice conditions on fuel consumption with- and without icebreaker support.
Vito Project: A Case Study Between a Development Operator and Pipeline Operators Advancing Deep Water Together
Authors: Preli Tom Anthony , Shirolikar Alok Dilip , Dick William Thomas , Thurston Kevin Wallace , Bougai Daria Igorevna , Cordoway Joseph , Dauterive David Michael
Published: April 2023

In 2009, the Vito field was discovered in more than 4,000 ft of water approximately 150 miles offshore from New Orleans, Louisiana. The project produces from reservoirs nearly 30,000 feet below sea level. This paper will discuss how a Deep Water development operator ("Development Operator") worked with two pipeline operators ("Pipeline Operators") to enable the Vito project and advance Deep Water together through care and simplicity. While the three companies had independent scopes of work, there were many opportunities for synergies during the project execution to deliver a cost competitive and integrated export solution. A "fit for purpose" approach was applied to achieve a common goal. The Vito project went through an optimization process called Minimum Technical Scope (MTS) to enable expected enhanced safety performance, better environmental performance, and lower unit development costs.

The topics discussed in this paper can be applied to future deep-water developments around the globe where the development operator does not have a direct ownership interest in the export pipelines. In addition, certain concepts could be applied on projects where the development operator is responsible for the entire deep-water development.

This paper discusses the scoping decisions taken across the integrated export system and how trade-offs were assessed to arrive at the MTS solution. The benefits that a common strategy can deliver for materials and installation, common construction equipment mobilizations and demobilizations, and the safety and environmental benefits from the coordination are addressed. Lastly, the paper discusses the working relationship between the Operators.

Cost competitiveness can be a challenge for every deep water project. Many of the items discussed in this paper hopefully provoke future development operators to apply some of the concepts so that deep-water can advance with care and simplicity.

This paper is part of a Vito Project series at OTC 2023, and the other papers are listed in the references.
Optimizing Subsea Processing for Deep and Long Step-Out Gas Fields
Authors: Pire-Le Gal Maëlle , Snoussi Wafa , Rondon Marianna , Laffray Gaëlle , Laudet Jean-Benoit , Palermo Thierry
Published: April 2023

In the current energy shortage and transition context, gas represents an alternative to provide an affordable, reliable and less GHG emissions issuing energy than other available fossil energies.

Flow Assurance studies have been launched for a series of gas fields to identify optimal subsea processing functional requirements for a subsea to shore export. The objective is to confirm the robustness of subsea processing architectures identified in previous studies and to evaluate their sensibility towards water depth, step-out, fluid composition and bathymetry.

First, real gas fields were selected, the portfolio was completed with notional cases constructed on analogs to reach a good mapping in depth and distance to shore. For each case, bathymetries and PVT models were established.

Ledaflow® was used to construct flow models and define the necessary pipeline size based on early and late life flowrates (based upon Erosion Velocity Ratio, Turn down and hydrate risk).

When the multiphase export required several pipelines in parallel, an alternative architecture was studied consisting of multiphase pipeline at early life and then gas/liquid separation plus single phases export (separated gas pipeline and liquid pipeline) for late life. Compression and boosting requirement were evaluated.

More than one configuration is technically possible. The solution of "multiple multiphase export pipelines" is usually in competition with a "single multiphase pipeline at early life coupled with a subsea separation at late life". The first configuration favors operational flexibility, while the second one favors reduced installation time and cost and allows decreasing the well head back pressure to increase reserves. However, this last solution still requires the installation of a liquid line at late life.

Regarding boosting requirements, each configuration has compression needs at late life. The first architecture allows to optimize the compression requirements and increase the process efficiency, while the second one present the drawback of high boosting requirements for the liquid line for great depth and longer step out.

For the multiphase export, and a field with very low CGR, the governing parameter for the pressure loss and the compression requirements is the step-out, not the water depth, while, for the subsea separation scheme, the water depth becomes detrimental for the boosting requirements of the liquid line for the great water depths.

This large study confirms the feasibility of subsea to shore architectures for gas fields and allows identifying the limitations of the existing technologies and anticipating future technological developments.
Designing A Data Buoy Network To Support Offshore Wind Energy Development In Southern New England
Authors: Kritzer Jake , Bland Katy , Shyka Tom , Motyka Jackie
Published: April 2023

Capitalizing on the considerable economic value and climate change mitigation benefits of offshore wind energy (OSW) while minimizing and mitigating its impacts on other ocean users and the marine environment requires a robust foundation of information. The Massachusetts/Rhode Island Wind Energy Area (MA/RI WEA) on the Southern New England Shelf is the first site of industrial-scale OSW development in the United States, and therefore where these challenges are first being confronted. Several sustained ocean observing buoys in the region provide valuable information for mariners, policymakers, and scientists, but additional data streams are needed in light of the forthcoming changes in use of the ocean. Therefore, we are investigating end-user data needs related to OSW development to inform the working design of a purpose-built buoy network structured around five priority issues: Navigation Safety, Marine Pollution, Fisheries Management, Wildlife Conservation, and Climate Tracking. Network design attributes sought by users include high-density measurements of the most important variables likely to be affected by turbines within the WEA while streamlining installation of additional infrastructure to the extent possible, a trade-off that calls for optimization analyses. Users also stressed the need to expand coverage of the shelf ecosystem given the bidirectional oceanographic, ecological, and economic interactions between the WEA and surrounding areas. We therefore identify an initial set of nine priority locations for ecosystem-scale observations. Observing in nearshore areas will be particularly important given the prevalence of vessel traffic, sensitive habitats, and human use close to shore. Priority measurements included a modest set of variables that characterize sea state conditions and weather to support Navigation Safety, along with a broader suite of ecosystem variables measured throughout the water column to inform other issues. As our research continues the working design will evolve, with the process ultimately aiming to provide lessons and precedent for how to build a robust information base for OSW development across the nation.
Diverless Solutions in a Diver Assisted Manifold for Readjustment of the Marlim Gas Mesh in Campos Basin
Authors: Santana Andre Luiz Bevilaqua , Da Silva João Luis Batista , De Souza Douglas Oliveira Correa , Cardoso Joaquim Pereira , Paixão Luiz Felipe dos Santos , Suci Felipe Mendes , Corrêa Ygor Fernandes Dos Santos Manhães
Published: April 2023

As in the world, the increase in the number of platform decommissioning projects in Brazil is directly influenced by the advanced age of some of the facilities, especially in the Campos Basin. Although the decommissioning phase is part of the life cycle of an oil development project and several similar projects have already been carried out in the Gulf of Mexico and the North Sea, the challenges in this sector are still enormous, especially in reducing operational risks, environmental impacts and financial costs.

Over the last few years, the company has sought to reduce divers' exposure to risk, as well as reduce this dependence on human diving in its underwater activities and reducing critical resources that impact underwater connections.

This article investigates the diverless trend in the global oil industry, demonstrating relevant aspects of this transition that involves replacing human diving in subsea operations with specific tools and ROV. In this sense, the operational and security aspects related to the theme will be explored. Using the descriptive methodology and considering the Marlim Gas Mesh Readjustment Project.

The objective of this work is to present the diverless solution that is being implemented for readjustment of the Marlim Gas Mesh in Campos Basin in a PLEM called MIS-MRL-1. As brief history is that the Manifold that was installed in a Water Depth of about 200m and was initially designed to be operated by saturated divers.
GHG Emissions: Evaluation, Reduction, and Reporting
Authors: Turner William Judson , MacKay Alexander Donald , Khurana Sandeep
Published: April 2023

The objective of this paper is to provide a systematic approach to verify and validate Greenhouse Gas (GHG) emissions for a typical Gulf of Mexico (GoM) offshore oil and gas production facility. The paper discusses ways to reduce GHG emissions at the facility level and examines an approach to assess an energy company's emission reporting methods and, where applicable, its target to achieve net zero emissions.

The paper reviews the regulatory framework for GHG emissions reporting and estimation guidelines. It identifies emission sources for a typical offshore facility and groups these emission sources into defined categories. A simplified model is created to estimate total emissions for offshore facilities. The model results are used to evaluate inherent uncertainty in emissions estimation techniques and also provide a basis to reduce emissions. Furthermore, the paper reviews sustainability reports of select energy companies, and analyzes these companies’ reporting methods, targets, and strategies to reduce emissions at the corporate level.

In summary, the paper provides insights and guidance in estimating GHG emissions at the offshore facility level and subsequent reporting at the company corporate level with the following:

Review of the regulatory framework, estimating methods, and reporting for an offshore facility level emissions. Organize emission sources into defined categories in order to comprehend major emission sources for an offshore facility. Analyze inherent uncertainty in emissions estimation. Discuss ways to reduce emissions at the facility level and its limitations. Analyze select energy companies’ corporate sustainability reports and cover ways to standardize emissions reporting so it is easier to evaluate and compare a company's performance with its peers. Identify energy company strategies and associated risks to achieve net zero emissions.
Predicting Reservoir Presence from Seismic Velocity Mapping and Pore Pressure Prediction
Authors: Legg Matthew James
Published: April 2023

Enhanced seismic velocity models (e.g. semblance or tomography) are key inputs for greenfield pore pressure prediction (PPP) in clastic basins, enabling velocity extraction along the planned well-path and also from a 3d earth-model surrounding the drill-site to test sensitivities and ranges. If velocity model resolution is sufficient, the resultant pressure gradients extracted along interpreted stratigraphic horizons from one of these three-dimensional (3D) earth models yields valuable insights into lateral pressure transfer efficacy, thus informing the net-to-gross (e.g. reservoir presence or absence) for the interval. The following inputs are required: 1) 3D seismic velocity model; 2) locally calibrated transforms for Compressional Velocity (Vp) to Vertical Effective Stress (VES) to generate a 3D pressure model from seismic velocities; 3) high-quality seismic interpretation horizons. The critical step is to extract from the 3D pressure model the pressure along each mapped horizon and plot the pressure with depth for each. For a shale horizon, the result reflects a linear shale gradient (e.g. ~0.83 psi/ft) consistent with restricted lateral pressure communication. Conversely, extraction along sand-interval yields a brine gradient (e.g., ~0.47 psi/ft) indicative of effective lateral pressure communication. Two Deepwater Gulf of Mexico (GOM) salt-withdrawal clastic mini-basins are depicted in seismic cross-section, each with representative suite of interpreted seismic horizons for pressure analysis within the depth-range of interest. It is not apparent to the uncalibrated-eye, in lieu of well data, which of the two is reservoir-prone and which is reservoir-absent. A detailed summary of methods and assumptions will follow, including empirical transforms, seismic earth cube generation, map-based extraction, and pressure gradient plots. The resultant gradient plots reveal one basin with uniform brine gradients and ubiquitous lateral pressure communication, compared with a suite of exclusively shale gradients in the other. Finally, well results, one test from each basin, confirm ubiquitous reservoir in the basin with the predicted brine gradients, contrasted with absence of reservoir in the basin with shale gradients. Following the presentation, the audience will require nothing more than graphical inspection of the event-extracted pressure gradient plots to discriminate a sand interval from a shale, and a reservoir-prone mini-basin from a reservoir-lean one.
Risk Based Verification for Subsea Pipeline Repair Connectors and a Case Study
Authors: Ouyang Simon , Tang Fei , Shavandi Mohsen , Cheng Chen
Published: April 2023

In Oil and Gas industry the Subsea Pipeline Repair Connectors have been developed to provide an effective sealing and installation on damaged or leaking pipelines. This paper presents a verification methodology for Subsea Pipeline Repair to confirm a product design compliance to DNV standards. It also introduces a case study for detailed design and qualification program approach for subsea pipeline repair connector to mitigate installation and operational risks. The purpose is to assist industry to mitigate operational risks and enhance safety.

As a case study, recently a type approval certification has been issued to a client for its subsea pipeline repair connector. This paper presents a risk based method towards verification of pipeline repair system, and it is focused on risk based methodology to address potential failure modes. The approach to address structural, sealing and gripping functions of the connector is discussed. DNV standards related to verification of pipeline connectors are also described in the paper.

Through this paper, the potential failure modes are discussed and the design verification process is described for the subsea pipeline repair connectors. The type approval process is introduced which consists of independent design review, sample testing and verification of quality controls. The results prove the approach is effective to assist the designer to bridge the gaps, mitigate the risks, provide the integrated solutions and enhance safety. Furthermore, the end user shall be benefit for mitigating the effects of unplanned repairs, improving the field’s uptime and restoring production quickly.

The novelty of this paper is the risk based verification of the pipeline repair connectors, which cost effectively helps identifying and mitigating the risks associated with failure modes and optimize the design of the pipeline repair system.
Joint Velocity Model and Microseismic Event Location Inversion Benefit the Measure, Monitor and Verify Value Chain
Authors: Le Calvez Joel , Mizuno Takashi
Published: April 2023

In carbon capture and storage projects, and in unconventional plays, microseismic monitoring and optical fiber are critical components of the measure, monitor, and verify value chain. A velocity model is required to estimate source location (hypocenter), source parameters, and source mechanism of a detected microseismic event. Incorrect event locations are often the result of an inaccurate knowledge of the velocity model. We propose a new method to simultaneously invert for the hypocenter and the velocity model to provide a robust long-term microseismic monitoring workflow.

Such problem has been studied in several areas of seismology over the last few decades. However, those studies focusing on large-scale earthquakes have remained of limited interest to reservoir-scale applications such as short-term and long-term microseismic monitoring and induced seismic monitoring. In such domains, the integration of sonic log-derived information into the joint inversion problem is critical as the scale is fundamentally different. Our algorithm respects the resolution of sonic measurement, while it calibrates the wavelength where microseismic data have sensitivity: the number of unknown parameters in the velocity model is decoupled from the number of layers included in the model. Therefore, we can solve for the velocity and event location inversion problem in a stable manner while respecting the resolution of the initial velocity model. In the present article, we introduce the science and technique behind the simultaneous inversion for the hypocenter and the velocity model and share case study applications based on a synthetic dataset and a real monitoring campaign.
Robotic Fish Enabled Offshore Pipeline Inspection
Authors: Wu Xuqing , Sood Tushar , Chen Zheng , Chen Jiefu
Published: April 2023

Timely inspection of subsea infrastructure, especially subsea pipelines, is the key to the prevention of oil spills. In this paper, a transformative offshore pipeline inspection technology is presented by using a bio-inspired autonomous robotic system equipped with a processing unit for underwater computer vision processing and edge computing. The goal is to build a time-efficient and cost-effective system for underwater pipeline inspection that can detect oil leakage at early stages and prevent disastrous results. In this paper, we introduced a bio-inspired autonomous underwater vehicle (BAUV) equipped with video cameras and mobile edge computing devices. We deploy a deep neural network (DNN) specially trained for a variety of underwater image/video processing tasks. The intelligent computer vision processing unit allows us to navigate and track objects even when the visibility is poor. This time-efficient and cost-effective solution will detect pipeline leakage and rupture at an early stage and allow operators to make timely and informed decisions to minimize environmental impacts.
Integrated Assessment of Seafloor and Subsurface Site Conditions at Atlantic Shores Offshore Wind Farm Development
Authors: Varnell Stephen , Trandafir Aurelian C. , Fortiz Victoria , Broughton Aaron , Scherschel Craig , Hargrave Deanne , Swanson Eric , Fraser Jack
Published: April 2023

This study illustrates a ground model approach used to characterize the complex site conditions within the Atlantic Shores Offshore Wind Farm Lease Area. The ground model is the result of the integration of geophysical, geological, geotechnical, and benthic (environmental) data to evaluate marine geohazards and summarize seafloor and sub-seafloor conditions. The ground model is provided in a Geographic Information Systems (GIS) format which can be interactively used for Wind Turbine Generator siting, design, and construction. Various components of the ground model including seafloor sediments and morphology, subsurface geologic features, stratigraphy, soil provinces, and soil profiles are presented and discussed. Soil province variability across the Lease Area has been successfully delineated in detail through the ground model methodology presented in this paper. Geotechnical properties of various identified soil units are generally favorable for a variety of potential foundation types and installation methods. This is one paper in a collaborative series that demonstrates the value of an integrated geoscience approach considering regulatory requirements and project design essentials.
Improving the Efficiency and Economics of Offshore Well Abandonment with Remote Well Monitoring Solutions
Authors: Kirker Christian , Krikke Tom , Rengers Frederik
Published: April 2023

Well annulus data is essential to designing well abandonment plans with minimal uncertainty, costs, and risks. Many operators are challenged with accessing data from wells in remote areas, which adds time and complexity to abandonment planning. This paper reviews a novel well-monitoring solution that continuously gathers and transmits well data from remote locations, allowing operators to develop decommissioning plans in less time, with less risk, and with fewer trips to the field.

Most modern well-monitoring systems are complex, expensive, and designed for high-producing wells. Such systems are not ideal for wells at the end of their lifetime. The novel monitoring service discussed in this paper provides 24/7 data collection and transmission for remote well decommissioning operations. The subscription-based, Internet-of-Things (IoT) service incorporates wireless pressure and temperature sensors, connectors, and a gateway technology to reliably collect and transmit data, via satellite, to onshore operations teams.

The service installs easily in just hours and is more affordable than traditional systems. In addition, the service's flexibility, scalability, and assured data security (via SOC 2 Type II-certification) make it applicable anywhere on Earth, regardless of power and connectivity infrastructure. Together, these features improve the efficiency and safety of decommissioning planning while lowering the operator's carbon footprint.

A major operator in the North Sea tested the remote well-monitoring service both onshore and offshore, prompted by the technology's ability to gather data automatically—with minimal engineers in the field. Previously, the operator spent tens of thousands of dollars and incurred greater risks by sending crews to the field to collect well data.

The successful field trial prompted the operator to expand the monitoring solution for long-term commercial installation. Following a two-hour installation training, the operator's field crews installed ten sensors and a gateway in a single day on one platform. The same crew installed 17 additional sensors on another platform in one day.

The service connected to the satellites in just 15 minutes and delivered well data with a reliability uptime of 99.8%. This data was 99.75% as accurate as the operator's existing systems, and a vast improvement on the 90% accuracy rating of many wired monitoring systems.

The service allowed the operator to reduce platform trips from four times to only one time per year. The service's data stream also identified information gaps and highlighted wells with unexpected pressure build-ups. This helped the operator avoid surprises to reduce decommissioning costs. Satisfied with these results, the operator has proceeded to implement the remote well-monitoring service in other wells around the world.
An Innovative Set of Tools for a Sustainable and Safe Offshore Pipelaying
Authors: Monacchi Giulio , Arcangeletti Giorgio , Pigliapoco Mauro , Catena Paolo , Ziero Loris , Castriotta Giovanni , Loi Alessandro
Published: April 2023

Offshore pipelay is a complex activity that is subject to some risks due to the challenging operating scenario. The risks may concern the workers during pipes handling, the subsea environment that may be subject to huge seabed rectification works and the integrity of the pipeline. This paper will present the technological roadmap developed by Saipem to implement a more sustainable pipelay operation, focusing on the safety and integrity of the environment, personnel and pipeline.

Four innovative tools will be described. The Hands Free Lifting Beam (HFLB) is a system for automatic offshore lifting of pipes, removing human intervention and keeping the workers away from the line of fire. The AFT (Anti Flooding Tool) is a remotely operated tool for pipeline protection from flooding in case of a wet buckle occurrence during lay. The I.A.U (Integrated Acoustic Unit) can perform a safe and non-intrusive, continuous piggability monitoring of the pipeline catenary during lay. The UCB (Underwater Cold Bending) is a solution for crossing sharp slope transition avoiding seabed preparation work and associated environmental impacts.

The HFLB grabs and lifts the pipes from cargo barge to pipelay vessel under the control of the operator located in a safe area. The AFT runs inside the laid pipeline during the entire lay, remaining in the safe section already laid (free from possible buckling running effects); it automatically plugs the pipe in case of an accidental flooding event, keeping safe the portion of the pipeline already laid. The I.A.U exploits the acoustic reflectometry and can be integrated with the ILUC (Internal Line Up Clamp) on firing line. It is an alternative to Mechanical Buckle Detector (MBD) which is an intrusive system with associated risks for the pipeline like wire break and loss of the device inside the pipeline, device stacking and possible damage of internal coating during pulling. The UCB is a combination of a new installation method and new subsea bending machine ROV operated, to realize cold bends safely and effectively on the pipeline profile without interrupting the continuous pipelay operation. The UCB can realize the bends underwater, directly on the pipeline catenary when the pipe joint to be bent is landing or close to landing on the seabed, reducing the operational cost while increasing the sustainability.

The presented tools can pave the way for safer worker operations during pipe handling (with HFLB); for de-risking the flooding of laid pipeline in case of wet buckle event avoiding the use of a dewatering spread and chemicals for seawater treating, reducing costs and environmental impact (with AFT); for de-risking the monitoring of pipeline during lay (with I.A.U) and for a sustainable crossing of steep escarpment without excavation works (with UCB).
Roadmap to Improve FPSO Integrity Management
Authors: Endress Ramos Julio , Cerqueira Trovoado Leandro , Curty Saad Arthur , Nogueira Diana , Gomes Silva Victor , Caldas Porto Bruno , Levin Lopes da Silva Gustavo , Costa Castelli Lucas , da Rocha Guimarães João Felipe , Pommerehn Vitiello Rodrigo , Souza Garcia Robinson Luiz , Badaró Moreira Agildo
Published: April 2023

Petrobras is the biggest FPSO (Floating, Production, Storage and Offloading) operator in the world having around of 25% of the market. The integrity management of such assets will shape the future of the Brazilian oil production in the next years. The implementation of state-of-the-art tools and the development of new solutions via R,D&I projects are important steps on the path to increase the integrity management evolution. Several programs and activities are in course on the three major related areas for the operational assurance of the asset: subsea, topsides and marine (including vessel structure). The inspection and maintenance markets were forced to accelerate the tools and systems development during the last years of Pandemic due to social distancing rules, so the need to remotely control activities and equipment became more important and valuable. The necessity to keep people away of the site has pushed the implementation of wearables, permanent monitoring systems usage, drones, robots and ROVs (Remoted Operated Vehicles), mini-ROVs and AUVs (Autonomous Underwater Vehicle). The operation team is currently investigating new ways to reduce human effort in tasks such as thickness measurement and visual inspection by using recent technologies to improve the inspection quality. This paper aims to outline the integrity management evolution roadmap, which is based on integrated programs on subsea, topsides, and marine inspection and maintenance that, working aligned, will end in a centrally stored collected data from several sources that will be available and displayed in each asset's Digital Twin model.