Day 3 Wed, August 18, 2021最新文献

{"title":"Aqueous Degradable Polyurethane Elastomers for Oil & Gas Applications","authors":"Matthew Peter Burdzy","doi":"10.4043/31186-ms","DOIUrl":"https://doi.org/10.4043/31186-ms","url":null,"abstract":"\u0000 A new class of patent pending aqueous degradable polyurethane elastomers have been developed that can be used in oil & gas exploration, drilling, completion and production where a degradable part is needed to provide a useful service life then quickly degrade when exposed to heat and water. This polyurethane technology eliminates the need for costly secondary operations such as milling, drilling or removing tools in downhole applications saving time and reducing cost. The degradable polyurethane is a low viscosity two-part heat cured elastomer that is easy to mold using low cost hot cast tooling techniques. The novel liquid polyurethane prepolymer can be formed into films, seals, sealing elements, tools, complex geometries or other aqueous degradable elastomeric components. The polymer is a tough tear resistant high strength elastomer with a tensile strength exceeding 5000 psi, elongation over 500%, and a 70% compression modulus greater than 13,000 psi. When integrated as a sealing element in a degradable hydraulic fracturing plug, the polyurethane is designed to be pumped down-hole, set and seal then degrade once the operation is complete. Once placed into service, the useful operating lifetime of this polyurethane chemistry is more than six hours when immersed in aqueous fluids at 80°C (176°F) (i.e. water or 3% potassium chloride). The elastomer can be compressed over 70% during its service-life providing a stable set of mechanical properties during use. The elastomer beings to fracture within two days and quickly degrades at 80°C (176°F) providing consistent and reliable results. Approximately 70% is completely water soluble while the remaining 30% fractures into small particles that can be easily removed or remain in the well. This paper reviews the development of the technology, applications, mechanical properties, service life, degradation profile and product life cycle.","PeriodicalId":11184,"journal":{"name":"Day 3 Wed, August 18, 2021","volume":"40 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85764124","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Corrosion Evaluation in Dual Completions Using a Multifrequency Electromagnetic Tool","authors":"J. Dai, A. Fouda","doi":"10.4043/30917-ms","DOIUrl":"https://doi.org/10.4043/30917-ms","url":null,"abstract":"\u0000 Early detection of corrosion in well casings is of great importance to oil and gas well management. A typical well completion includes a production tubing inside a number of nested casings, which provide necessary well integrity and environmental protections. A multifrequency electromagnetic pipe inspection tool with multiple transmitter and receiver arrays was designed to accurately estimate the individual wall thicknesses of up to five nested pipes. The tool uses an axis-symmetric forward model to invert for wall thicknesses, among other pipe parameters. However, in cases where production occurs from two or more segregated zones, the well is generally equipped with more than one production tubing, which breaks the axial symmetry. In this paper, we show how the tool can further be employed to inspect the integrity of non-nested tubulars, such as dual completions. The performance of the tool is demonstrated using a full-scale yard mockup with known defects.\u0000 A data-processing workflow, including multizone calibration and model-based inversion, is proposed to estimate the tubulars electrical conductivity, magnetic permeability, wall thickness, and eccentricity. An in-situ, multizone calibration method is applied to remove adjacent tubings influence, thus enabling accurate estimation of the thickness of outer casings without having to pull out the production tubing.\u0000 In order to demonstrate the capabilities of the tool in wells with dual completions, a log was run in a 150 ft-long yard mockup with two strings of 2⅞ inch. tubing, two outer casing strings, and four different man-made defects on the casings. The tool is logged inside each of the tubing strings, and the two logs are inverted for the thickness and eccentricity of the tubing as well as the thickness of outer casings.\u0000 Results from the yard test reveal that when the tool is logged in one tubing, it can accurately detect various kinds of defects on outer casings, even in the presence of a second tubing. The interference from the second tubing is shown to be minimal due to the employed calibration algorithm. A high degree of consistency is seen between the logs run in each tubing string. This suggests that if the goal is solely to monitor corrosion in the outer casings, it suffices to run the tool in only one of the tubing strings, further cutting nonproductive time.\u0000 The techniques presented here enable pipe integrity monitoring without pulling the production tubings; tubings, therefore, minimizing inspection time and cost. The information provided by this tool can significantly improve the efficiency of well intervention operations, especially in areas with high corrosion rates.","PeriodicalId":11184,"journal":{"name":"Day 3 Wed, August 18, 2021","volume":"23 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76878755","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Are You in the Green? The Economic Impact of Carbon-Conscious Choices on Project Development Planning","authors":"D. Choe, J. Whitworth, Ashutosh Kak, Genevieve Bisset","doi":"10.4043/30947-ms","DOIUrl":"https://doi.org/10.4043/30947-ms","url":null,"abstract":"\u0000 The greenhouse-gas (GHG) emissions target set by UNFCCC Paris Accord in 2016 will emerge as a new value driver to project development planning that has the potential to degrade the viability of future offshore oil and gas projects. Integration of GHG emissions and legislated carbon price as new decision drivers to project decision-making will require an in-depth understanding on the overall economic impact of carbon-conscious choices. In this light, the purpose of this paper is to present the impact of such choices on project development planning and implications for Decision Quality (DQ).\u0000 The case study presents a comparative assessment of total GHG emissions and comparative project economics for a Greenfield project, considering four development concepts: a Reference Case with a \"traditional\" offshore facility and three hypothetical cases, each of which are defined, evaluated, and compared against the Reference Case. Development of each case is discussed and created to support decision-making during project development planning. The paper presents an economic comparison to demonstrate the importance of including a carbon assessment early in project development planning to assure a thorough concept evaluation. It also demonstrates how a clear outlook on the annual GHG intensity over project life can be vital, for project sanction and mitigation of high carbon cost penalties in the future regulatory landscape.\u0000 Early understanding of risks associated with carbon price and regulatory enforcement can potentially change how industries analyze the viability of their projects/assets. The paper demonstrates the importance of assessing carbon-conscious options early in the project development planning stage, and how this helps developers to navigate the risks and opportunities in the drive to a lower-carbon society.","PeriodicalId":11184,"journal":{"name":"Day 3 Wed, August 18, 2021","volume":"391 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77122857","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"New Downhole Sand Entry Detection Technology Leads Directly to Successful Remedial Work and Additional Oil Production","authors":"G. Agrawal, Moustafa Eissa, Kamaljeet Singh, Shaktim Dutta, Apoorva Kumar, U. Okeke","doi":"10.4043/31210-ms","DOIUrl":"https://doi.org/10.4043/31210-ms","url":null,"abstract":"\u0000 The consequences of sand production are often disadvantageous to the short and long-term productivity of the well. Although some wells routinely experience controllable sand production, these are the exception rather than the rule. Sand production and its management over the life of the well is not an attractive situation but is often essential to extract the resource. Knowing the root cause behind sand inflow in a well and the possible results can inform an appropriate strategy to safely extract as much of the resource as possible.\u0000 The sands in such reservoir units often have high permeability and are mechanically weak and prone to sand production. The producing wells are often completed with gravel-packed completions for efficient sand control. Most of the wells have multi-zone completions for better productivity but this further complicates reservoir characterization.\u0000 This paper describes the first use of downhole sand impact detection technology in such fields. The sand detection technology integrates the fully digitized high-resolution acquisition with signal processing and interpretation algorithm to enhance the sand particle detections as small as 0.1 mm in diameter and up to 1,500 impacts per second. The tool is designed to immune the sensors from any background noise and gas/liquid jetting effect.\u0000 A combination of production logging tools (PLT) and the sand impact detection tool, was used to understand four phase zonal contributions (gas, oil, water and sand) and pinpoint sand entry in these cases. Results exceeded expectations and the ability for the sand detection tool to accurately detect the point of sand entry enabled immediate intervention to eliminate sand production in these case studies. One of them also resulted in increased production of 7.4kb/d oil without any sand flow and with greatly reduced gas-oil ratio as compared to pre-intervention production.\u0000 The work clearly demonstrates the practical and effective use of downhole sand impact detection with new sand detection technology to identify and isolate sand production in wells. The innovative tool design makes it feasible to detect even small sand particles in adverse wellbore conditions and varied production rates, thus adding a detection of the fourth phase in an otherwise three phase production log.","PeriodicalId":11184,"journal":{"name":"Day 3 Wed, August 18, 2021","volume":"14 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84326771","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Umbilical-Less Tubing Hanger Installation Controls System","authors":"T. Lovland, Trond Lokka","doi":"10.4043/31142-ms","DOIUrl":"https://doi.org/10.4043/31142-ms","url":null,"abstract":"\u0000 The umbilical-less tubing hanger running installation tool, ROCS (\"Remote Operated Control System\") was first introduced as an R&D project to the market in early 2020. By February 2021, it is in operation for Aker BP in the North Sea on Deepsea Nordkapp.\u0000 ROCS is specifically designed to increase the robustness and efficiency of running the production tubing in the well. In a traditional operation, the Tubing Hanger Running Tool (\"THRT\") normally communicates topside through an umbilical. The ROCS eliminate the controls umbilical by having two methods of communication to the THRT, either acoustic or through wired pipe, preference is acoustic. This also eliminates the topside WorkOver Completion System (\"WOCS\"). The approximately 16meter long ROCS is also designed with a Ready To Run (\"R2R\") principle, where the ROCS, THRT and Tubing Hanger (\"TH\") is made ready on land for offshore operations, already connected and tested.\u0000 The system is redundant and based on a closed loop hydraulics, powered by a subsea HPU, electrically supplied from subsea batteries. The SHPU is small in size and power consumption, capable of providing the required flow at 690bar. The control functions occur through electrically held DCV's (\"Directional Control Valve\") for controlling all of the required TH functions. The ROCS is capable of performing 3 operations of each TH function within the allocated deployed period. The energy required is provided between the hydraulic accumulators and batteries. Pressure balanced accumulators are included to optimize all deepwater operations. A properly sized clean reservoir is installed, interfacing the pre charged accumulators. ROCS is controlled through a modular and user-friendly topside HMI (\"Human Interface Machine\"), communicating acoustically or through wired pipe over any type communication protocol.\u0000 The benefits include removing personnel from red zone, as well as eliminating time to clamp umbilical to the drillpipe. This significantly reduces mobilization of the system to a few hours, which also eliminates the topside deck space considerably. The running time is reduced and allows to increase speed of the drill pipe. This also reduces the risk of damaging production tubing or downhole equipment. There is no risk of downtime due to damaged conduit and the operating weather window is increased.","PeriodicalId":11184,"journal":{"name":"Day 3 Wed, August 18, 2021","volume":"12 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86668369","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Innovative Energy Storage Concept for Saipem Offshore Wind2Sub™ Application","authors":"Enrico La Sorda, F. Pucci, B. Mauriès, Birgitte Storheim, Giorgio Arcangeletti","doi":"10.4043/31220-ms","DOIUrl":"https://doi.org/10.4043/31220-ms","url":null,"abstract":"\u0000 Reducing CO2 emissions is becoming one of the core targets for countries after the Paris agreement, which sets out a global framework to avoid dangerous climate change by limiting global warming to below 2°C and pursuing efforts to limit it to 1.5°C. To meet this objective also oil and gas operators have started to engage in an important effort to reduce the CO2 emissions in their plants and facilities.\u0000 From this perspective Saipem developed its Wind2Sub, a Wind Power for Long Subsea Tie-Back (LSSTB) concept, where its own pendular floating foundation solution, namely Hexafloat, can host a wind turbine generator (WTG), all the utilities needed for subsea field development and operation (power distribution, chemical storage and injection, control system) and a back-up energy system to compensate the intermittent production due to wind persistence, currently a diesel generator (DG).\u0000 The present paper will explore new solutions to ensure the continuity of the energy supply from Saipem Wins2Sub, based on green technologies. This may be done by collecting the generated surplus energy from a renewable energy system, in this case from WTG to a topside or subsea power storage. By adopting an Energy Storage System (ESS), it will be possible to use this energy when production from wind is low or null. This concept will replace the diesel generators, or any carbon fuel, so that the whole system will become green self-sustaining, as an energy island, without CO2 emissions.\u0000 The activities performed during the concept development are articulated through the following steps: a selection of two typical oil field scenarios where Wind2Sub solution can be applicable; screening of the current technologies to store energy and a selection of those viable to the two selected scenarios; wind conditions and WTG power analysis with estimation of the amount of the energy to be stored; preliminary design of the ESS; preliminary cost estimation.\u0000 The study was carried out by using a digital tool developed by Moss Maritime in the context of a Proof of Concept based on Floating energy storage. The tool allows to evaluate the feasibility of a solution through modellization of different renewable energy scenarios, demand profiles, simulation of operation, pre-sizing of the systems and cost estimation (LCOE, LCOS, LCOH).\u0000 The ESS combined with Saipem Wind2Sub will be described more thoroughly in the present paper through the explanation of the results achieved within the case studies.","PeriodicalId":11184,"journal":{"name":"Day 3 Wed, August 18, 2021","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91198488","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Density Measurement of Three-Phase Flows Inside of Vertical Piping Using Planar Laser Induced Fluorescence PLIF","authors":"A. McCleney, K. Supak","doi":"10.4043/31327-ms","DOIUrl":"https://doi.org/10.4043/31327-ms","url":null,"abstract":"\u0000 Planar laser induced fluorescence (PLIF) is a measurement technique that can be used to provide a laboratory reference for validating the performance of field instrumentation that either directly measures mixture density or infers it from a combination of ancillary techniques. PLIF density measurements offer high-speed response and the ability to resolve minute flow features in transient flow patterns. Fundamentally, PLIF can also be used to verify multiphase flow models and predictive tools that are used for designing production piping. The use of PLIF to determine an instantaneous mixture density of two-phase flows has been successfully accomplished in previous fundamental laboratory studies found in literature. However, the use of this technique to determine the mixture density of three-phase flows for field-related scenarios has not been previously evaluated. To assess PLIF as a potential reference measurement system, a testing effort was undertaken to measure the instantaneous mixture density from a comingled oil-gas, water-oil, and oil-water-gas flow that was subjected to slug, churn, and bubble transient flow conditions inside of vertical piping. The objective of this work was to compare and validate the results obtained using the PLIF measurement approach against a commercially available gamma densitometer and tomography system for a variety of flowing conditions. The PLIF technique was able to resolve transient flow features and density values for both two-phase and three-phase flows through the piping. Distinct slug flow features such as the slug head, gas pocket, pocket collapse, and the tail were captured by PLIF and were observable in the raw image sequence captured by a high-speed camera. Additionally, the results for a variety of water-oil-gas flowing conditions were within 3% difference of a mixture density model that was calculated from liquid and gas flow measurements utilized in the test facility. The comparison of the PLIF results to the reference instrumentation indicates that this technique is successful at obtaining a mixture density for steady and transient oil, water, and gas comingled flows.","PeriodicalId":11184,"journal":{"name":"Day 3 Wed, August 18, 2021","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90939657","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Planning for Unknown in The New Age of Digital: A Paradigm for Offshore Oil and Gas Risk Assessment and Management","authors":"H. Hamedifar, Herve Wilczynski","doi":"10.4043/31057-ms","DOIUrl":"https://doi.org/10.4043/31057-ms","url":null,"abstract":"\u0000 Major Oil and Gas operators and service companies look to undertake large scale digital transformations aimed at producing integrated, connected, and intelligent enterprises. These transformations require accelerating the journey to the cloud to modernize the entire application portfolio. By transitioning to the cloud, firms enjoy improved data analytics which allow for evolution to next generation digital work environment. This shift, however, comes with workforce challenges. Employees in all categories and at most levels will require significant cross- and up-skilling to take full advantage of the digital transformation. As vendors, suppliers, service companies, and operators move products and equipment around an expanding ecosystem of assets, security threats are likely to increase due to further geopolitical instability. Data based decision making, which enables the optimization of assets and automation of operations to minimize workforce risk exposure must be implemented with consideration of enterprise risk reduction (across the asset and workforce operational risk life cycle).\u0000 As Oil and Gas operations become more geographically dispersed and diverse, they are exposed to new and evolving risk factors which can directly impact value. These risk factors make asset acquisition, development, management, and maintenance all more challenging. Analyses of risk in a digital foundation risk-based platform is most valuable at the earliest stages of asset development in determining whether to proceed with the planned development through to end-of-life decommissioning. Successful firms must create an end-to-end digital roadmap which delineates between technical and transactional activities and outlines effective stakeholder engagement at each project stage.\u0000 The fundamental thesis of this paper is that although risk can be mitigated and reduced through the introduction of digital tools into oil and gas operations, it can never be completely removed. Furthermore, while industry research on the impact of digitalization usually rely heavily on cost savings, optimization, and health, safety, and environment (HSE) related cases, they typically fail to consider the contribution of digitalization on risk assessment and management. This paper argues that we need to move away from the focus on cost savings, process optimization, and HSE metrics improvement metrics. This paper sets up a mechanism for developing risk-based strategies for implementation of digital solutions.","PeriodicalId":11184,"journal":{"name":"Day 3 Wed, August 18, 2021","volume":"68 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89946967","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The Effects of Low Temperature Carbon Diffusion on Stainless Steel","authors":"P. Dymond, A. Bauer, D. Cummings","doi":"10.4043/31207-ms","DOIUrl":"https://doi.org/10.4043/31207-ms","url":null,"abstract":"\u0000 Stainless steels along with Nickel based alloys are often selected for many applications in corrosive environments. While resistance to corrosion makes them a favorable choice, poor tribological behavior may prevent a broader use of these materials. The Kolsterising® process is a proven method for the surface hardening of these materials by the diffusion of carbon. This paper intends to highlight the improvements typically seen in key mechanical properties including resistance to galling, wear resistance, and fatigue life. Untypically, due to the nature of the process, these properties are generally improved without the usual associated reduction in corrosion resistance. Property improvements will be demonstrated using both new and existing data from Europe and North America.","PeriodicalId":11184,"journal":{"name":"Day 3 Wed, August 18, 2021","volume":"43 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85049481","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"On the Subsea Production System Availability with Resident Drones. A Reliability, Availability, Maintenability RAM Analysis","authors":"M. Mattioli, A. Padova","doi":"10.4043/30918-ms","DOIUrl":"https://doi.org/10.4043/30918-ms","url":null,"abstract":"\u0000 The challenge in the Oil&Gas industry to remain competitive in a low oil price whilst dealing with minimization of operational risk and uptime asset maximization is leading offshore Companies to evolve thought proactive and predictive maintenance approaches. In the event of unplanned intervention due to anomalies or warning messages at the dispatching center, the decision on the size of the support vessel and its utilization for straordinary maintenance could be time consuming with potential high cost impact, also due to loss of production. Even the new generation of remote condition and monitoring systems, which allow to improve the capability of operators for early warnings and surveillance, provide a reliable solution for emergencies. In this context, resident subsea drones enable on-demand inspection whilst eliminating the need for support vessel and allow operator to manage the risk in continued operations also for dangerous areas restricted to human access.\u0000 A case study relevant to a new subsea field development have been conducted. Distinctive Reliability, Availability and Maintainability (RAM) analyses have been performed with the aim to get insight on the subsea production system availability considering a resident drone and to demonstrate how the so called \"stategic maintainability\" can be applied successfully in the decision-making process while reducing the OPEX. The former related to conventional IMR (Inspection, Maintenance & Repair) based on Condition Based and RBI, Risk Based Inspection approach, the latter related to strategic maintenability with resident drones. The application of such analysis required a multi-disciplinary approach together with the possibility of processing historical data in operating conditions. Historical data sources (e.g. OREDA dataset) were collected to obtain failure rates and active repair times typical of subsea equipment. Direct experience gained in over forty years of inspection and maintenance activities together with recent developments on subsea resident robotics allow the understanding of real internvention timing.\u0000 Results show that resident subsea drones applied for early inspection and light intervention are confirmed timely and costless solution respect to conventional IMR services. They represent the first aid for environmental surveillance and subsea inspection in case of emergency and provide a relevant saving of subsea production un-availability.\u0000 The economic value emerged from the presented case study represents a step change for OPEX optimization and motivates Best-in-Class Operators to get an insight case-by-case for both green and aging fields.","PeriodicalId":11184,"journal":{"name":"Day 3 Wed, August 18, 2021","volume":"20 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78853300","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}