bluuebunny/crossref_metadata_2025_split huggingface dataset:
Lower FPSO Carbon Footprint Through Hydrocarbon Blanketing
Authors: Bárcia G. S. , Bronneberg J. , Cerqueira H. 
Published: October 2023

FPSO crude oil storage tanks require a blanketing on top of the stored crude and FPSO Cargo Tank operations are characterized (for the purpose of current paper) by the displacement of the tank vapor during the loading cycle by produced oil and, reversibly by the vapor re-filling of the tank volume during the offloading operations.
In cargo oil tanks during offloading operations the tank is "topped-up" with blanketing gas to replace the displaced liquid volume and, during loading cycles the vapor is displaced so that the liquid can occupy the volume. Traditionally, the vapor ullage in the tank is composed of inert gas and, during the loading cycle until the start of the offloading, the gas is in equilibrium with the crude oil, so its composition changes through time due to the vaporization of hydrocarbons. Consequently, its calorific power is not constant so it cannot be reused in the process stream. For this reason, at every loading cycle the vapor phase of the cargo oil tank is vented, contributing to greenhouse gases emissions.
There are several possible methods to decarbonize offshore operations of FPSOs, as shown in Figure 1. Hydrocarbon Blanketing is one of these several alternatives and it allows for the recovery of volatile components otherwise released to atmosphere. As will be demonstrated in the paper, it has a considerable positive environmental impact, reduction in corrosion and safety benefits and is relatively simple to implement ("low hanging fruit").
Assessment Methodology for Transition of Offshore Brownfield Platforms to Remote Operations
Authors: Aisamuddin Pi Remli M. , Fatimah Samsu M. , Halim Firdaus A. , Kuanji Jennyfer Joseph 
Published: October 2023

Abstract
Remote Operations (RO) for offshore brownfield platforms in PETRONAS (to be referred as Company) refers to the use of digital technologies and remote monitoring systems to operate and manage existing oil and gas facilities. It involves the implementation of digital solutions and advanced technologies such as the Industrial Internet of Things (IIoT), Artificial Intelligence (AI), and Time to Failure (TTF) Machine Learning (ML) to optimize the performance of existing assets and ensure safe and efficient operations.
The detailed assessment to evaluate and frame RO gaps and requirements are divided into three main processes consisting of Operability Assessment, Reliability, Availability and Maintainability (RAM) Assessment and Value Trade-Off Assessment to ensure the delivery of value driven design and concept for RO.
The details of the three processes are as follows:
Operability Assessment – To identify manual intervention activities that are required in managing normal and abnormal operations by evaluating as is gaps for each level of RO. RAM & Scenario – To simulate the platform availability number for each scenario according to RO modes. Value Trade Off Assessment – To evaluate each RO scenarios against CAPEX investment and OPEX reduction where the optimum scenario should be selected.
Through Detailed Assessment, each platform in Malaysia Assets was evaluated on the potential of RO end state level to be implemented.​ Implementation of RO is targeted to minimize or eliminate human intervention at site as well on console by improving control and automation. The implementation shall give significant value with unmanned philosophy since it will require less support in logistic and eliminate other associated cost for manned operation.
Subscribing to this new operating condition through detailed assessment evaluation while embracing digital and technology transformation for current oil and gas platform in operation is novel in COMPANY operation. Rethinking of the current Asset Operation & Maintenance (O&M) towards Remote & Integrated Operations results in value driven operations, improved operational efficiency, enhanced safety, increased asset reliability and reduced costs. In addition, it opens the door to be agile in addressing current pain points and provide solutions to sustain asset life in view of declining production.
Challenging the 30 m Annulus Cement Requirement
Authors: Arild Øystein , Lohne Hans Petter 
Published: October 2023

Abstract
The permanent plugging and abandonment of a well requires the establishment of at least two barriers according to the NORSOK D-010 standard. In common practice, a barrier is either a cement plug from formation to formation, which is all cement, or a combination of existing cement behind the annulus, the casing steel itself and a cement plug inside the casing, see Figure 1. The latter case is a cheaper and preferred solution as milling can be avoided and thus reducing cost, environmental footprint and a number of potential operational hazards. The cement between the casing and the formation is called the cement sheath and has typically been in place since the well was constructed. The evaluation of the status of this barrier element after years of production – called verification in many standards – is conducted using different types of logs. Leakage through the cement sheath can happen in three ways; along the interface between the cement sheath and the casing, leakage through the bulk cement itself as the cement has a certain permeability, leakage in cracks or channels present in the cement sheath and finally leakage between the cement sheath and the formation. Significant leakage through the cement sheath prior to permanent P&A typically causes an increased annulus pressure, which is monitored and dealt with if it happens prior to permanent P&A.
In order to qualify the cement sheath when using the NORSOK D-010, 30 m of good bonding is required, i.e. the interface between casing surface and the cement is good in terms of that it most likely will not represent a leakage path along the interface, so called micro annuli. Logs are best at detecting interface phenomena and good logs means that we have strong indications that there are no micro annuli, but logs may also indicate weaknesses in the bulk cement between the casing and the formation.
Shallow Water Mapping: Remote Solution for Global Satellite-Derived Sea-Floor Mapping
Authors: van de Poll Robert , Smith Jason , Chatten John 
Published: October 2023

Abstract
Qualitative site reconnaissance from satellite imagery offers critical insights about shallow-water areas, including coastal zones, river deltas, estuaries, lakes, ponds, etc. This information is critical when considering proposed sites for new infrastructure. Whether a ports and harbor project, fiber-optic cable landing site, offshore pipeline or power cable landing for a new offshore wind development, identifying potential hazards or constraints saves time and money. Using 2D raw global coverage satellite imagery, it is possible to create 3D seabed geomorphologic deliverables for preliminary shallow water hazard and site assessment. This approach has been used in 145 Countries on 2,200 projects over the past 07 years. Because underlying data deliverables are sourced from 2D optical satellite imagery, assessments are limited to 10-20 m water depth, dependent on the atmospheric and water quality conditions. Archived images can deliver a 10-year historical analysis, offering valuable insights to seabed changes over time. Deliverables of this technique comprise a series of satellite images, referred to as 4D seabed surface morphology (4DSSM) image technology. Deliverables are offered at two precision levels. Level 1 involves 6300-plus TB of global coverage imagery available in archives, where 10 m ground resolution 3D image deliverables enable shallow-water seabed assessments. Level 2 involves 10-plus PB of global coverage imagery available in archives, where 30-70 cm ground resolution 3D image deliverables enable shallow-water seabed assessments (needing higher resolution localized analysis), depending on site specific requirements. While true depths are not determinable from optical imagery, qualitative information on hazards and changes in sedimentation distribution patterns, uncharted seabed hazards, existing seabed infrastructure and other constraints are easily identified, providing a valuable tool for nearshore vessel activity and infrastructure development needs. Satellite imagery is an effective tool for qualitative site reconnaissance in the shallow water coastal zones. As offshore development becomes more prevalent, accurate seabed mapping is crucial. While nautical charts were once the primary source of information about the seabed, these data are often outdated and inadequate to inform early planning of new offshore developments. Advanced satellite-based mapping techniques can provide up-to-date seabed morphology data for advanced planning and decision-making on offshore projects.
A Comparative Approach to Gas/Liquid Separation Technologies for Subsea Applications
Authors: Shaiek S. , Giolo R. , Moraes C. A Capela , Bacati F. 
Published: October 2023

Abstract

Objectives/Scope
Subsea separation refers to separating the production flow into its different phases (gas/liquid or liquid/liquid), mainly based on density differences between components, at the seabed.
The implementation of a subsea separation system allows for reduced back pressure on the subsea wellheads resulting to the increase of oil recovery and to the extension of production field lifetime while optimizing surface or onshore facilities.
Subsea Gas/Liquid separation allows to develop deepwater oil and gas fields with improved Flow Assurance philosophy while optimizing the overall production operability and fluid processing on topside.
As the industry needs to tackle challenges of deeper and higher-pressure fields, the subsea Gas/Liquid separation systems need to fulfil many requirements to allow for effective developments.
The paper focuses on Gas/Liquid separation providing a comparison of different separation technologies that could be applied subsea. A systematic approach is proposed to cover process performances, operational robustness, flexibility, and maintenance requirements.

Process
An initial description of available technologies is presented. Gravity based separation vessels cyclones, including Gas Liquid Cylindrical Cyclone technology (GLCC) and inline cyclonic devices, and the subsea Vertical MultiPipe (VMP) are discussed.
The main parameters evaluated for each technology with respect to their potential subsea use is listed.
Also, to guide the assessment of separation technologies, a notional reference case, featuring typical specifications for a deepwater development, is proposed.

Results, Observations, Conclusions
Based on the relevant parameters, especially identified for subsea applications, and reference case data, a ranking of technologies is presented. Moreover, a sensitivity allows to extend the considerations beyond the studied case showing where the various technologies are advantageous. Additionally, maturity and technology gaps for subsea applications is discussed.
Finally, the results show that, compared with the other technologies, the VMP provides a simpler and reliable design while providing a maintenance free solution.

Novel/Additive Information
The paper presents a thorough analysis of Gas/Liquid separation technologies applicable to subsea deepwater field development based on qualitative and quantitative results.
It gives an overview of advantages and limitations of each solution to support proper selection to any specific field.
Challenges in Riser Fatigue Estimations from Simultaneous Processes
Authors: Skrede S. O. , Sødahl N. , Sletten J. S. , Drabløs S. O. , Grytøyr G. , Hogg B. , Gregersen K. , Farnes K. 
Published: October 2023

Abstract
Deep-water steel lazy wave risers and steel catenary risers are subject to simultaneous loading from different sources. Environmental loading comes from waves and vortex induced vibrations (VIV), and in addition internal slug flow may also excite dynamic stresses. Design codes account for this either by applying conservative damage summation formulas, such as the method from DNV-RP-C203, or by recommending adding stresses in time domain. Actual design practice is more inconsistent, with different levels of scientific foundations, like, e.g., linear summation of damage contributions. A study has been performed to assess methods for combining fatigue damage from two independent simultaneous processes. This has been studied for time series simulated directly from spectra, and on simulated response time series of a deep-water steel lazy wave riser. The case study considers two loading combinations: Two years of measured environment (waves, current profile), divided into a series of short-term conditions of waves and VIV. This gives a consistent description of the long-term fatigue loading from waves and current, taking the correlation into account.Representative slugging conditions for the lifetime of a field, combined with wave scatter.
Global riser analyses have been run in time domain for waves and slugging, and in frequency domain for VIV. For best-estimate results, combined analyses have been run for waves and slugging, and time series of stresses have been combined for waves and VIV. Linear combination of damages has been applied on the separate results to compare with the best-estimate approach.
The results show, as expected, that the industry approach of linear summation of fatigue damage from two processes is unconservative. The amplification of fatigue damage due to an additional process is considerable, even for comparably low stress ranges.
Although the study is focused on steel lazy-wave risers, the problem itself is generic and applies to other structures exposed to combined fatigue loading, such as flexible risers, dynamic umbilicals and cables, subsea spools, etc.
Key Takeaways from Implementing a Successful Downhole Scale Mitigation & Prevention Job in an Indian Western Offshore ESP Well
Authors: Uniyal Rishabh , Jaruhar Suman Kumar , Sarkar Manoj Kumar , Devshali Sagun , Parida Dibyajyoti , Bhoye Sushil , Biswas Sudipta , Dodda Dhiraj 
Published: October 2023

Abstract
Multiple ESP wells in an Indian Offshore Carbonate reservoir were afflicted with inorganic scale deposition chronically. Analysis of recovered deposit samples was carried out and the root cause of deposition established. This was followed by successfully carrying out remedial operations for scale removal and prevention. The experience gained from the same has been elaborated in the paper.
Inorganic scale deposition in Electrical Submersible Pumps has been a big cause of concern in many wells of a carbonate reservoir in Indian Offshore. Scale deposition in ESPs causes decrease in pump efficiency and sometimes, complete choking and ultimate failure. As part of this study, a detailed Compositional Analysis of recovered samples retrieved from inside the ESP was carried out. Based on the analysis, custom job plans were formulated to clear the scale from within the ESPs and its vicinity. This was followed by a continuous inhibitor injection program from a downhole chemical injection mandrel after the selection of the appropriate chemical.
The results of the compositional analysis of the recovered debris showed that despite the well operating in a carbonate reservoir, the majority of the sample was acid-insoluble sulphate scale. Further probing elucidated the fact that multiple acid washes had been performed in the well, which while dissolving the carbonates, left behind insoluble sulphates as residual scale. The operating conditions inside the pump were also especially conducive for sulphate deposition. As such, tailored job plans consisting of a formulation of a chelating agent in an alkaline solution were designed and executed. Implementation of the job plans resulted in significant oil gain from the affected wells and the continuous inhibitor injection has further improved the efficiency of the ESPs and reduced the frequency of cleaning jobs required.
The paper aims at providing an insight into inorganic scale deposition in ESPs. After analysing the scaling problem and establishing the root cause, mitigating measures have been devised and implemented. The paper provides a holistic approach towards tackling the problem of existing inorganic scale and preventing future deposition from taking place. The experiences gained during the entire exercise have been deliberated in the paper.
Evaluation of Carbon Footprint Reduction for a CO2 EOR Injection Scheme Field Pilot
Authors: Diaz O. Castellanos , Katiyar A. , Figueiredo P. , Groothuis E. , Watty J. P. , Crosley M. 
Published: October 2023

Abstract
Enhance oil recovery using CO2 as a solvent is posed to be a major technology in producing energy with a lower carbon footprint. It is therefore important to operate such technologies in an efficient manner. Foam-assisted technologies in which a surfactant aids conformance of the CO2 in-situ, allowing it to produce oil more effectively. This CO2 foam assisted EOR may be a critical technology if the CO2 utilized is of anthropogenic origin and is eventually sequestered underground. As such, having a framework where the potential benefits of foam-assisted technology are calculated is relevant. A calculation framework is introduced in this work with a life cycle thinking approach. To showcase the calculation methodology, a field trial is taken as an example of a successful EOR intervention technology. A field pilot from a trial between The Dow Chemical Company (Dow) and ConocoPhillips (Now Maverick, SPE 201199) is used. Injection and production data, together with industry averages on electricity generation, gas compression, and water treatment, were utilized to calculate energy input into the process prior, during, and post-trial. With this, a reduction of carbon footprint of 17% was realized together with a 30% reduction of freshwater use.
Well Planning Solutions Tailored to Meet Atlanta Field Directional Drilling Challenges
Authors: Macedo R. R. , Aguiar R. , Freesz C. A. , Costa W. , Alcantara A. , Souza M. G. , Sanchez L. , Salies J. 
Published: October 2023

Abstract
Atlanta is an oilfield located offshore Brazil known for its challenging directional drilling control. Its relatively shallow sandstone reservoir requires horizontal wells to maximize pay zone drainage. The objective of this paper is to describe the planning and execution phases of a successful project in the third drilling campaign in the field. To meet the geological requirements, the proposed well plan aimed to kick off from vertical just below the conductor casing shoe.
The tailored well design met the specific directional drilling needs of the operator. The phase two OD was initially drilled in 12 ¼" using a mud motor with AKO = 1.7° and then a new BHA was run in hole to under ream to 16" and then to 20". This work shared the BHAs designs and the operational strategies implemented in the project. To ensure a flawless execution, a 24/7 support team service was deployed to assist offshore operations, providing real time optimization services, such as vibration control, performance drilling and KPIs to measure operational effectiveness. A drilling automation service monitored torque and drag, and for potential borehole cleaning issues: comparing the theoretical broomstick against the actual torque and drag values automatically identified any unexpected change in the trend patterns.
The drilling automation service reduced back-reaming requirements by allowing data-driven decisions. Analysis of the BHA performance in the 12 ¼" section, and the subsequent under reaming 20" BHA, yielded relevant information for similar applications.
This unique well project provides the industry a different approach for offshore directional drilling in unconsolidated formations. This case study illustrates well planning solutions that decrease the operational risk of missing geological targets.
Remote Satellite Controlled Underwater Visual Inspection and Measurement System
Authors: Medagoda Lashika , Galea Mitchell , Bruggen Thomas Van , Martins Paulo , Castillo Marco 
Published: October 2023

Abstract
This paper outlines the remote visual underwater inspection technology using the Lantern Eye Stereo Remote system, a non-contact stereo imaging system that can be deployed without an imaging engineer offshore, allowing scaled 3D models and measurements. This system allows an imaging engineer to operate remotely, linking the mounted camera system used off-shore on an ROV, to an on-shore office. The connection was facilitated by a satellite connection to the ROV Support Vessel (RSV).
The approach was achieved through a novel communication architecture using a deployed computing system, VPN and multiple subnets. The communications are enabled through a robotics middleware that handles the publishing and subscribing of information including compressed images, and commands that change the exposure and gain of the camera system. Additionally, real-time photogrammetric reconstruction allows the on-shore user to understand in real-time the coverage that has been achieved on the mapped object. This makes sure that the required data has been captured, as the data collection process can be complex and tracking the collected data is error prone.
The system allowed multiple successful deployments, without the requirement for the imagine engineer to be offshore with the camera system during data collection. Results show that the system can be applied to any offshore deployment. In situations where the bandwidth is reduced, there is scope for increased compression on the images, but there exists hard requirements on bandwidth and latency where performance degrades beyond feasible usage, which has been determined to be 0.6MB/second (5Mb/s), 1500 ms latency. In the case of stable water conditions, a higher latency can be tolerated due to the simpler data capture process. For future work, greater reliance on the computing platform that is deployed with the camera system is possible, which includes automation of the role of the onshore imaging engineer, including automatic adaptation of image parameters without human intervention, and ensuring coverage is attained without a human monitoring this live. This opens the scope of future work where greater automation is undertaken with significantly less human intervention, for situations with low bandwidth and high latency.
This paper adds to the state of knowledge which benefits the oil and gas industry through showing an operating example of the remotely enabled subsea integrity assessment. This reduces the personnel required offshore and opens the path to further automation of the data collection process, especially in cases of reduced bandwidth or high latency. This opens up further benefits such as less vessel time.