bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Novel Subsea Connector for Repairing Clad Pipelines
Authors: Mattarucco Riccardo , Trevisan Alberto , Giudicianni Carlo , Lucchese Francesco , Toso Gianluca 
Published: April 2023

Abstract
Subsea pipeline repair connectors have been used in the oil & gas industry for many years and are considered a valid and safe way of repairing major damages and restoring the original pipeline condition in case of an emergency repair; they can also be used for tie-ins to allow extensions by connection of new pipeline sections to an existing one and they have an extensive track record mainly on carbon steel pipelines but are fit also for stainless steel and duplex pipelines. The increasing number of subsea pipelines with internal CRA cladding which have been deployed in recent years and are foreseen in the future poses new technological challenges since conventional sealing solutions are not suitable for or have limitations in this specific application: in this case the repair connector not only needs to be designed to be compliant with the sour product but it also needs to protect the pipeline carbon steel wall from coming into contact with the internal fluid. This paper presents a new concept of a pipeline repair connector that has been developed from the beginning specifically to target repairs on sour service lines and in particular on clad lines.
This innovative repair connector is based on a metal to metal sealing technology that offers permanent repair without any reduction of the pipeline's internal diameter, provides a versatile diver/diver-less solution, can deal with multiple wall thicknesses and can also be applied to other types of pipelines, such as those for sour service with internal corrosion allowance since it can manage pipe wall thickness reduction over time.
The design of the mechanical connector has been carried out in compliance with DNV pipeline codes after a comprehensive technology qualification testing campaign under DNV certification and focused on medium size pipes. A full-scale 26″ prototype connector has been designed and fabricated for completing the qualification testing program including all required pressure and loading conditions. FEM analyses of the testing configurations have been carried out for comparison with test data so to validate the FEM models and extend results to other sizes within a predefined range. The matching between the experimental data and FEM calculations has allowed setting up a Type Approval process with DNV and, after a design effort covering various pipeline sizes and types, the connector will be certified for a wide range of large bore pipelines and design conditions and be ready for release to the market.
Eliminate Section Milling in Plug & Abandonment Applications with Liquid Thermite
Authors: Levchenko Andre , Clark Billy Ross , Carragher Paul John 
Published: April 2023

Abstract
This paper presents a novel technique for section milling that decreases costs involved in preparing a section of an oil and gas well for permanent P&A. Testing results have shown that this novel technology is capable of melting steel tubulars, control lines and associated clamps in fluid at pressure in both laboratory and well environments. Laboratory work provided data to develop models for window length predictions based on length of thermite column used, and well pressure predictions during the thermite reaction. Melted window lengths of as long as 2m have been achieved in large-scale testing and field trials, along with validation of predictive models. This leap forward in section preparation technology will save millions of dollars of operational expense compared to traditional section milling methods for P&A. Combined with alternative barrier materials such as Bismuth-based alloy plugs this novel technology will be truly rig-less P&A solution for oil and gas well that have reached the end of their lifecycle.
Top of the Line Corrosion Management for Wet Sour Gas Subsea Pipeline
Authors: Abbas Faisal M , Ganugapenta Venkateswara R , Ghurab Abdullah A , Alharbi Abdulwahab B 
Published: April 2023

Abstract
Gas sustainability mandates effective pipeline corrosion management programs, especially for wet sour non-associated gas trunklines. This paper highlights the reengineering of top-of-line corrosion (TLC) management for wet sour gas subsea pipelines. The paper details the strategies adopted for improving the existing V-jet batch inhibition treatment program and summarizes the latest research efforts in sour top-of-line corrosion prediction modeling and effective alternatives to V-jet batch inhibition.
Risk-based methodologies are adopted for ascertaining the batching frequency for TLC inhibition in the sour subsea pipelines. Corrosion monitoring data coupled with Inline Inspection data are used for comparing the actual corrosion rate against the model predictions. Laboratory analysis are performed to evaluate the efficacy and persistency of the corrosion inhibitors. Field trials are performed to validate proposed scraping frequency optimizations. Field corrosion data is used for improving the TLC modeling through a joint industry program.
The methodologic approach materialized significant improvements in operations and integrity management of long subsea pipelines. Pipeline scraping frequencies and associated chemicals consumption are reduced, flaring is minimized, and the processing capacity of existing assets is increased. The efforts have also resulted in improving field avails and reduced facility downtime and maintenance efforts. Joint Industry Programs resulted in improved TLC modeling and initiated the development of standardized testing protocols for Vapor Phase Corrosion Inhibitors and Batch Corrosion Inhibitors. Additionally, improvements are made in the aspects of 1. Facilities, and 2. Processes and Practices for improving subsea pipeline integrity management.
High Precision Seabed Deformation Monitoring
Authors: Davis Eric , Krug Ralf , Debastiani Deyvid , Oliveira Camylla , Pereira Leonardo Cabral , Rachid de Araujo Marco Aurelio 
Published: April 2023

Abstract
Deformation monitoring has been conducted on land for many decades to observe fluid movement in reservoirs, determine hydraulic fracture orientation, and confirm cap rock integrity. The three technologies currently in common use for land-based deformation monitoring are: electrolytic tiltmeters, GNSS and InSAR (Interferometric Synthetic Aperture Radar). Each technology has a different set of strengths and weaknesses, which are in many ways complementary. Tiltmeters have a high temporal rate and provide far higher precision than GNSS or InSAR but require careful instrument layout planning to ensure that precision translates from gradient changes to elevation changes. The uncertainty from tiltmeter arrays also increases with time if there is no absolute reference in the array. GNSS is much lower precision and relatively high cost per installation, but its stability over time can mitigate long term drawbacks of a tiltmeter-only installation. InSAR has a limited temporal rate and can suffer from uncertainties due to a variety of causes, but the enormous coverage area that is often available with minimal or no ground instruments makes it a strong asset in many monitoring programs.
GNSS and InSAR both rely on microwave frequency signals, and so are not directly applicable in the subsea environment. Acoustic analogs exist, but only with lower resolution that renders them of very limited use for monitoring small deformations, including those induced by most processes that are well below the seabed. Tiltmeters can be used in the subsea environment, but deployment methods to date, mostly by the scientific community for seamount and tectonic fault monitoring, have placed instruments directly on the seabed and suffered the consequences of low precision. Instruments on land are typically buried 6 to 12m to isolate them from noise sources at the near surface, which are primarily diurnal thermal disturbances. Best precision typically requires maximum thermal excursions on the order of 1e-3 C near the instrument. Since even the deep ocean generally experiences temperature fluctuations of several tenths to several whole degrees C, placing the instruments on the seabed severely limits the usefulness and application range. A new deployment mechanism enables mechanically and thermally stable placement of tiltmeters in seabed sediment at depth, with acoustic transmission for data retrieval. High resolution tilt measurement of the seabed allows the same diagnostics previously only available on land to be obtained in the more challenging and higher consequence offshore environment.
An array of instruments deployed off the coast of Brazil in March 2021 is furnishing key information on reservoir fluid balance, providing insight into the impacts of changes in injection and production and enabling better decisions on reservoir management.
A Machine Learning Approach to Improve the Reliability of Aging Tendon Tension Monitoring Systems
Authors: Ng Jimmy Keong Tark , Maroju Soma Sekhar , Das Suvabrata 
Published: April 2023

Abstract
Tendon Tension Monitoring Systems (TTMS) are commonly installed on Tension Leg platforms (TLPs) to measure the axial tensions in the tendons. These measurements are essential to the weight management of the platform, and in monitoring their fatigue life. The TTMS typically consists of 3 load cells per tendon, with 2 bridge measurements for each load cell. This makes up to 6 tension measurements per tendon allowing for a good number of redundant measurements for tendon tension determination. This system design with redundant measurements allows for long term integrity monitoring of the TLP, and some of these systems have been in operation for over a decade. However, the degradation of the load cells over time due to harsh environments, wear and tear, reduces the reliability of the tension measurement system.
This study investigates the use of machine learning (ML) to model tendon tensions using historical TTMS data with reduced number of reliable tension measurements. Building models, training and validation of these models are evaluated and presented to demonstrate how ML can provide reasonable tension estimates and help extend the useful life of the TTMS. Outputs from these models are presented and discussed, with a focus on accuracy in relation to the number of model inputs. Observations from models simulating reduced inputs with no TTMS measurements from at least one tendon are elucidated. This paper demonstrates how ML from TTMS data can estimate tendon tensions reasonably, with a reduced number of reliable measurements. Implementation of these techniques can help to extend the useful life of these TTMS.
Evaluating an Area of Review for CO2 Sequestration and Storage: A Subsurface Modelling Workflow Tied to Regulatory Guidelines
Authors: Umrani Rahul , Jones Ryan , Ware Chuck , Janise David , Ozah Robin , Joshi Nikhil 
Published: April 2023

Abstract
In United States, decarbonization of Carbon Dioxide (CO2) intensive industries is becoming a priority to meet the goals of the ‘Paris agreement’ which is to limit global warming to 1.5 °C. CO2 capture and sequestration (CCS) is an efficient technique to reduce anthropogenic carbon emissions and curtail the impact of climate change. CCS involves capture and permanent underground storage of CO2 which would otherwise be released into the atmosphere into deep saline or depleted hydrocarbon reservoirs. Selected Oil & Gas Exploration and Production companies with upstream expertise are exploring CCS to reduce the broad industrial CO2 footprint. Sequestration of CO2 in the subsurface requires robust techniques to be implemented to monitor the progression of the CO2 plume and the consequent increase in subsurface pressure. The regulatory authorities therefore require evaluation of an Area of Review (AoR) which is a project area that is under the influence of CO2 injection activities. AoR is defined as the project area in which elevated injection zone pressure may cause upward migration of formation fluids into the closest underground source of drinking water (USDW) through a potential geological or mechanical leakage pathway.
Pursuant to the Underground Injection Control (UIC) program, US Environmental Protection Agency (EPA) regulates CO2 sequestration wells by the enforcing Class VI permits. Only five Class VI permit applications have currently been reviewed and approved by EPA and state regulatory authorities (USEPA 2023). In this fast-evolving CCS space, understanding key terminologies of the Class VI permit such as AoR is one of the challenges faced by the industry. The aim of this paper therefore is to explore the AoR concept as stated in the US Code of Federal regulations, provide an interpretation of key terminologies involved and demonstrate how a reservoir modelling workflow can be utilized to delineate an AoR.
The study summarized by this paper employs a conceptual saline reservoir model developed with geocellular property and facies modelling that is representative of a certain US Gulf Coast area. This model is dynamically simulated by incorporating CO2 – rock interaction flow physics. Reservoir simulation provides predictions of subsurface movement of the CO2. These results are coupled with current guidelines provided by the regulatory authorities to evaluate the AoR as the CCS project progresses over time.
Continuous evaluation of AoR provides a robust level of due diligence to prevent the CO2 plume from encountering geologic and mechanical leakage pathways to the surface or overlying sources of drinking water. This technique can also be utilized to prevent the CO2 saturation front from exceeding acreage boundaries that have been prescribed for CCS.
Subsea Tool for Hose Retermination Using ROV
Authors: Corrêa Ygor fernandes Dos santos manhães , Santana Andre luiz Bevilaqua , De souza Douglas oliveira Correa , Junior Ricardo Nascimento deslandes , Schueng Hugo Martins 
Published: April 2023

Abstract
Offshore oil and gas production systems comprise a variety of subsea arrangements dedicated to serving production platforms and export lines. Hydraulic systems are widely used in offshore production systems, particularly for control and operation of Wet Christmas Tree, Manifolds, Valves and others equipaments. Subsea umbilical hydraulic fluid leaks are a problem for the oil industry because they cause environmental damage and involve equipment downtime with financial losses associated with oil and gas production. Leaks, mostly internal, represent one of the most common failures in hydraulic systems.
The Campos Sedimentary Basin occupies a marine area located in the region from the central-northern part of the state of Rio de Janeiro to the southern part of the state of Espírito Santo. This field comprises a geological structure that has provided the accumulation of the remains of marine organisms over millions of years. The region currently accounts for about 30% of the entire national production and there is still a lot of potential to be developed. Within the company, there are approximately 280 producing wells in operation, approximately 7,000 employees working on the most diverse fronts, and 25 offshore platforms in operation.
This paper presents a study of solutions developed to contain leaks in hydraulic umbilicals, using robotic techniques with ROV support. The anomaly that occurred in equipment connected to the PGP-1 in Campos Basin, resulted in significant losses. The area responsible for studies and the company's underwater repair service is responsible for designing and developing solutions for repair services for rigid pipelines in contingency situations and support in the inspection and maintenance of pipelines and underwater equipment.
In the past, the repair or replacement of subsea umbilicals was done with the assistance of human divers, more precisely in the saturated mode. This type of assistance is a methodology that presents high risks to the safety of the professionals involved. Another relevant issue is the high costs involved in renting a Diving Support Vessel - DSV and the limitations of using this vessel in adverse environmental conditions (wind, current, wave height, etc.).
ETH-PiP 2.0 Experience from Fenja EPCI
Authors: Marret Antoine , Helland Torgeir , Papore Eddy , Le-Naour Frederic , Pratt Ed , Vivet Romain , Møller Fredrik Andreas , Haugen Knut Edmund 
Published: April 2023

Abstract
This paper presents the foundations as well as the main outcomes of the development, industrialization, fabrication and installation of the TechnipFMC's Electrically Trace Heated Pipe-in-Pipe (ETH-PiP) 2.0 for application on the Fenja field development.
The Fenja Field is located offshore mid-Norway at a water depth of approximately 324m, and consists of two separate hydrocarbon accumulations, the Pil and Bue reservoirs, with fluid properties leading to flow assurance challenges such as hydrates and wax formation. Following successful deployment of a first generation of Electrically Trace Heated Pipe-in-Pipe on the TotalEnergies (then Total) Islay Field in 2011, TechnipFMC have conducted the development and industrialization of a completely new generation of ETH-PiP 2.0.
The new ETH-PiP 2.0 has higher electrical rating of 3.8/6.6kV to overcome the specificities of the Fenja field development including the long tie-back distance of 36.8km which makes Fenja the longest (and largest) ETH-PiP in the world.
Subsequent to successful qualification of the ETH-PiP system, TechnipFMC has completed the manufacturing of 36.8km of ETH-PiP stalks at the Evanton spoolbase. These were then loaded out onto the Deep Energy pipelay vessel for subsea installation by reel lay.
The installation was finalized in summer 2021 with the complete system being connected and tested from the Njord A platform after it returned from refurbishment in spring 2022.
This paper presents the qualification, industrialization, assembly and installation of the new generation ETH-PiP 2.0 which forms part of the Fenja field development.
Electrification Solution for Greenfield and Brownfield Facilities Utilizing Offshore Floating Microgrids, as an Alternative to Power from Shore
Authors: Maisey Joel Alan Brant , Brown Steve 
Published: April 2023

Abstract
The United Kingdom (UK) is driven to reduce offshore emissions by the North Sea Transition Deal (NSTD) agreed between industry and the government in March of 2021. This agreement requires the UK offshore industry to reduce emissions against a 2018 baseline, with interim goals on route to being net zero by 2050. The most pressing target is a 50% reduction by 2030.
To achieve these goals, groups of facility operators and their Joint Venture (JV) partners have begun progressing power from shore solutions exclusively, thus not considering alternative electrification concepts. As a result, the North Sea Transition Authority (UK regulator) launched "The Decarbonization competition for the electrification of offshore oil and gas installations", working with the Department for Business, Energy & Industry Strategy (BEIS), to fund technical and commercial studies on alternative offshore electrification in the UK North Sea. With the benefit of this support, the Orcadian consortium has developed an off-grid, or Microgrid, approach to platform electrification, as an alternative to power from shore.
The Orcadian consortium Microgrid delivers a practical and achievable solution, enabling field operators to meet and likely exceed the North Sea Transition Deal emission reduction commitments The key benefits of the Microgrid are: Emissions reductions – approaching an 80% reduction for offshore facilitiesLower costs – saving almost $2 billion and more than 25% cheaper than the power from the UK grid option, when capital and ten years of operating costs are included, for a subset of platformsA practical way for operators to meet their North Sea Transition Deal commitments in terms of both the emission reduction targets and timeframeDeliverable quickly, and in phases, which allows a staged deployment with a steadily improving reduction in emissionsOpportunities for re-use or redeployment – provides legacy infrastructure for the grid and/or other usersApplications beyond oil & gas to provide reliable, low carbon power to industry or national power grids.
Efficient Welded Joint Sealing System for Pipe with Thermoplastic Liners
Authors: Sears Ryan M. , de Oliveira e Silva Jose Anisio 
Published: April 2023

Abstract
Thermoplastic pull-through liners are an effective method or preventing corrosion of carbon steel pipe. Offshore pipelines using thermoplastic liners require a means of welding pipe joints without damaging the heat-sensitive liner. Methods used to date include the use of corrosion- resistant alloy (CRA) connectors that place the plastic liner far enough away from the weld zone to prevent heat from damaging the liner, and thermoplastic connectors that utilize insulation and/or an annular air gap to prevent heat from damaging the plastic liner at the weld zone. In the case of the latter the thermoplastic connectors require electrofusion welding of the connector to the liner in the pipe, which is time consuming.
This paper reviews the design and shop tests of a welded joint sealing system that permits the use of insulating thermoplastic connectors that seal to the liner in the steel pipe by means of a mechanical seal. This welded joint sealing system permits far faster joint assembly in the field than other methods, by avoiding the time-consuming processes of CRA welding or electrofusion of the thermoplastic connector to the thermoplastic liner in the steel pipe. The joint assembly process on a lay barge takes seconds per joint and is orders of magnitude faster than other methods, making it economically feasible for use in J-Lay and S-Lay vessels.
Hydrostatic pressure tests have proven the welded joint sealing system to consistently prevent liquids from reaching the weld zone at pressures exceeding 500 bar. The key to achieving the mechanical seal is the novel means of locking the thermoplastic liner to the steel pipe wall. By preventing the liner from moving inside the steel pipe, it is possible to provide a fixed seat for the thermoplastic connector to seal against.
Weld tests have proven that weld quality is unaffected by the connector and that heat exposure to the connector is below the degradation threshold of its thermoplastic material.
The welded joint sealing system provides a cost-efficient, highly repeatable means for protecting the weld zone of thermoplastic lined steel pipe from corrosion. It makes it economically feasible to use thermoplastic liners for the transport of corrosive and hazardous liquids, including the use of specialty thermoplastic liners in case of high temperature sour oil and gas.