bluuebunny/crossref_metadata_2025_split huggingface dataset:
Quality Assurance on Annulus Isolation Under Well Cementing Uncommon Events – Practical Approaches in Deepwater Wells
Authors: Moreira R. P. , Ribeiro D. B. , Lima L. B. , Piedade T. S. 
Published: October 2023

Abstract
Defining acceptable criteria for primary cementing operations has always been challenging. When unconventional events or conditions occur during the cement job, the potential impact on future well integrity shall be evaluated before proceeding further operations during well construction. This study aims to describe practical approaches on evaluating zonal isolation based on cementing design robustness and post job signature when such unconventional conditions are present in Brazilian deepwater wells. A large database for well casing cementing scenarios in Brazilian deepwater fields provides information to correlate and identify the most present cementing abnormalities and undesired well conditions prior to cementing and the quality of annular isolation through cement evaluation logs ran. The analysis, additionally to the operational normality evaluation, considers different scenarios such as the presence of extensive salt zones, low-fracture gradient formations, ballooning plastic formations and the different cementing strategies performed in each well. The data provides evidence that fluid losses and cementing hardware malfunction are the most common failure modes for annulus isolation in the deepwater wells analyzed. However, there are situations where these abnormalities do not interfere in cementing quality, and a more detailed analysis should be performed to identify if an impaired condition will occur. Two case studies detail the process, the first for salt zone cementing in pre-salt wells show that it is possible to identify the loss zone depth through job parameters, and the second case study for two-stage cementing in post-salt wells show that it is possible to identify impact on casing hardware malfunction. Although the common practice of cement evaluation under cementing abnormalities takes the running of logs to identify impact on zonal isolation, the approach here described consider an engineered analysis on the job parameters that may simplify the process safely and lead to cost reduction for casing cement quality assurance.
Dynamic Wettability Alteration at Pore-Scale Using Viscoelastic Surfactant/Chelating Agents Systems
Authors: Ahmed M. Elmuzafar , Sultan Abdullah S. 
Published: October 2023

Abstract
The role of wettability is crucial in the extraction of hydrocarbons as it determines how well the oil adheres to the rock surface, directly impacting the efficiency of the extraction process. Numerous studies have been conducted to modify the wettability of rocks to a favorable state. In this study, we delve into the microscopic level to observe the actual process of altering the contact angle during flooding using microfluidic technology within a glass micromodel. Initially, the micromodel is saturated with formation water and subsequently displaced by oil to establish the initial oil saturation. The microfluidic setup consists of a precise pump for flood control and a high-speed microscope to capture images for later analysis using image processing software to obtain the actual contact angle. The contact angle is measured at five arbitrary locations, and the average is calculated at specific time intervals based on image analysis. Three different fluid systems were utilized: pure Viscoelastic Surfactant (VES), VES with DTPA, and VES with GLDA. The concentration of these systems was selected based on optimal rheology and interfacial tension performance. The contact angle was measured at various injection stages to observe its dynamic change from the initial state to the final state and assess the resulting recovery from each fluid system. The pure VES system modified the wettability from slightly oil-wet to slightly water-wet and achieved a 48% recovery of the original oil in place (OOIP). On the other hand, the addition of DTPA altered the wettability from slightly oil-wet to extremely water-wet; however, this did not lead to higher recovery, and water breakthrough occurred, reducing the sweep efficiency with a 45% recovery. The GLDA VES system altered the wettability to moderately water-wet, which proved to be the most favorable wettability condition, resulting in a 56% ultimate recovery. This investigation successfully demonstrated the effectiveness of using VES-assisted chelating agents in altering rock wettability and increasing oil recovery at the pore scale.
Non-Intrusive Level Measurement Using Guided Elastic Waves
Authors: Gorski Dmitri , Lieske Uwe , Neubeck Robert , Witsø Peder Solum 
Published: October 2023

Abstract
Accurate level measurement in process vessels is important for safety, production optimization and control as well as for optimization of chemical additives. Most of the level measurement sensors used in oil and gas production today are Differential Pressure (DP) transmitters, displacers and, sometimes, Guided Wave Radar (GWR). More advanced profiler-type sensors are used more rarely and most often only for process analytics. Almost all of the commercially available level measurement instruments are intrusive, meaning that they require a flange or penetration for installation and maintenance. In practice, this implies that installation and maintenance on an existing installation have to be conducted during a turnaround. This makes such a project prohibitively expensive considering the cost of turnaround time and the fact that a turnaround on an offshore platform is only performed once every 1-4 years.
This work describes pilot trials with a novel non-intrusive level measurement system that utilizes Guided Elastic Waves (GEW) for attenuation tomography. Pilot experiments were carried out in a model separator with an internal diameter of 1.00 m and length 3.75 m. The pilot separator which was filled to pre-determined levels with tap water, mineral oil and construction sand. Flow of water was induced in some of the experiments. Phase levels were recorded manually through a sight glass and compared to readings generated by the novel measurement system.
Experiments showed that the novel level measurement system is able to detect levels of sand and liquid as well as clean water/oil interface levels with very high accuracy. Flow had no significant influence on the measurement results and the sensor output remained stable over the cause of one month. After the successful testing, the system has been qualified for its first trial on an offshore installation. In addition to an offshore pilot, more R&D needs to be conducted in order to develop capabilities to measure emulsion and foam interface layers as well as to determine how fouling by scale, waxes and other impurities present in a full-scale separator influence the measurement.
Integrated Approach Combining Plant Data and Thermodynamic Simulation for Management of Inorganic Scale in Topsides Processing Facilities
Authors: Neto S. Simoes , Smiderle A. L. , Neto J. M. Dias , Alves A. F. 
Published: October 2023

Abstract
A major concern with pre-salt processing is the water salinity and its high scaling potential. High standing output levels necessitate an effective scaling management strategy. One element of a successful program is scale prediction, which is frequently done utilizing the produced water's thermodynamic equilibrium.
This paper presents a methodology and algorithm to systematically calculate scaling index of produced water blend to be compared to representative brines which were defined for scaling inhibitor design tests. Thermodynamic calculations of calcite saturation indexes at relevant process conditions are evaluated for the mixture of produced wells streams and for the platform critical brine.
It was implemented an algorithm that integrates plant historian database to thermodynamic calculation routines and presents the results in a user-friendly web portal for proper visualization. Calcite saturation index is calculated using Pitzer activity model which is often used for calculations of inorganic scaling potential in high ionic waters. Produced wells flowrates are used for defining mixture fractions of the produced blend. For each platform there is one representative brine composition that was used for scale inhibitor design, herein called the platform critical brine. However, the compositions of wells produced water are updated as soon as new water analysis is available. The algorithm creates a scaling index (ISS) based on calcite saturation indexes that measures how far from the critical brine the produced mixture is in relation to calcite saturation index.
The ISS is evaluated systematically in daily basis for several platforms offshore Brazil. The results show how the different wells configurations (flowrates) impact the produced water blend criticality with respect to inorganic scaling. The implemented routine gives insight to production engineering personnel regarding potential problems with scaling and chemicals design. It can be used to assess if the platform critical brine should be updated, and possibly new chemicals designed. Additionally, the ISS can be used to optimize the topsides process conditions in specific scenarios.
The processing conditions and produced water compositions of pre-salt oilfields offshore Brazil results in scaling potential at topsides. This paper describes the methodology applied for monitoring the scaling potential systematically on a daily basis for several pre-salt platforms.
Marine Vibrator Milestone: A Pilot Seismic Survey
Authors: Alfaro R. , Secker S. , Zamboni E. , Guitton A. , Cozzens A. J. , Henderson N. , Nechayuk V. , Jenkerson M. , Johnson G. , Karran J. 
Published: October 2023

Abstract
The Marine Vibrator Joint Industry Project (MVJIP), sponsored by TotalEnergies, Shell and ExxonMobil, completed a successful pilot survey in Q3 2022 using two Integrated Project Node (IPN) Marine Vibrators in an offshore European open water setting.
The IPNs were deployed in two configurations: one under tow, and the other stationary at each shot point. Various sweep types and duty cycles were also tested. An airgun source of equivalent energy size was also used for comparison. Throughout the pilot the IPNs demonstrated exemplary performance. There were no HSE incidents during the project, nor was there any technical downtime related to the IPNs. Moreover, real time quality control results were able to show the IPNs high fidelity with respect to the pilot sweep and excellent sweep-to-sweep repeatability.
A fast-track processing sequence was completed, which showed that the IPNs have been able to image the subsurface very well including steeply dipping reflectors. This demonstrates the progress that has been achieved by the MVJIP over the last 10 years and gives a real impetus to continue the development of the marine vibrators into a commercial source. The next steps will be to complete a more comprehensive full processing sequence on all the lines to extract the best possible images.
Development and Evaluation of Asphaltene Inhibitors for Offshore Brazilian Crudes
Authors: Ewbank Conrado Gerard , Clements John , Deluge Max , Rabelo Rodrigo Balloni , Dezotti Rafael Sobral , Dallaqua Roger Pezzuol 
Published: October 2023

Abstract
Asphaltene deposition has been an extremely critical flow assurance challenge in the Oilfield industry and the chemical treatment with continuous asphaltene inhibitors injection has been one of the best solutions for operators to face this challenge preventively, especially in the offshore market where it has the presence of extreme application conditions. This study focuses on optimizing the selection of the best chemicals and dosages of asphaltene inhibitors in Brazilian offshore crudes quickly and effectively.
Combinations of different techniques and surfactants (non-ionic and polymeric surfactants) were evaluated in this study. To determine the best solution to be used for these systems, studies were carried out through the colloidal characterization both of asphaltenes in petroleum and of the effect of additives on the asphaltene deposition mechanism using LUMiSizer (Dispersion Analyzer), an equipment that enables extremely effective techniques, with high sensitivity and fast response time, applied for different Brazillian Offshore crude oils To determine the kinetics of destabilization and a tendency of asphaltene aggregate formation, data were acquired from LUMISizer, confirming the minimization of aggregate growth in more stable systems. Results also indicate the existence of a minimum effective concentration, suggesting a minimum dosage that promotes coating in the flakes formed, so that the steric barrier is effective in the curvature of the growth and deposition of asphaltenes. The LUMiSizer was used to rank the efficiency of different inhibitors and dispersants for a specific oil. Such results are even more informative than just saying whether an inhibitor is suitable or not.
Study on Emulsification Characteristics and Anti-Emulsification of Emulsions for Offshore Thermal Well Production Fluids in Bohai Bay, China
Authors: Hao Liu 
Published: October 2023

Abstract
Cyclic steam injection is one of the most effective EOR technologies for Bohai off-shore heavy oil field. Production capacity of thermal recovery has reached 1.9 times of cold production in the same period. However, with the increase of huff and puff cycles, large amount of water-in-oil emulsion is produced with water cut increasing gradually, especially in the range of 30-50%, which leads to poor oil-water separation effect on the platform's heating dehydration equipment, and even causes the working current of the electric dehydration equipment to be too high, resulting in the increase of water cut of the exported crude oil. At the same time, oil-water emulsification may block the formation pore roar, affecting the oil flow channel, resulting in the reduction of thermal production.
Our work is mainly focused on the emulsification characteristics and Anti-emulsification of the emulsions from thermal well production fluids. Based on the characteristics of the produced liquid during thermal recovery and injection, a high-speed disperser is used for preparing water-in-oil emulsion. Effects of water cut on emulsion viscosity, crude oil and emulsion are carried out by using remoter, one-dimensional core displacement device as well as microscope. Meanwhile, microscopic characteristics of emulsions, and phase state of cores and dynamic anti-emulsification of cores are also studied.
The results show that with the increase of water cut, viscosity of the emulsion increases greatly, which is risen to 5.9 times more than that of crude oil when the oil-water ratio is 5: 5. At the same flow velocity, the pressure gradient of the emulsion in the low-permeability core tube of 1000 μm3 is significantly higher than that of crude oil. In the hypertonic tube of 3000 μm3, the difference between the pressure gradient of the emulsion and the crude oil is not obvious at the same percolation velocity. Testing results show that the emulsion increased the maximum steam injection pressure to 3.15 MPa. After adding the anti-emulsion demulsified solution to the emulsion, the number of water drops was extremely reduced. The demulsifier has dual functions of anti-emulsification and reducing steam injection pressure in rock core.
Anti-emulsification can effectively reduce the emulsification degree of the produced liquid in thermal recovery of offshore steam huff and puff, so as to improve the thermal recovery effect.
Offshore Mature Fields in Deepwaters: The Final Challenge
Authors: Pedroso Carlos A. 
Published: October 2023

Abstract
Increasing the recovery factor of a mature field should be a top goal for every petroleum engineer. Producing oil from mature fields is both strategic and necessary: ​​Necessary because we need to increase our efficiency and reduce our carbon footprint. And it is unreasonable to leave in the rock a resource that nature took millions of years to generate. And strategic because oil from a mature field is (or should be) cheaper and has very low risk: I know where it is, I know how to produce it and I know what not to repeat.
However, producing onshore mature fields is much simpler than offshore. It is common to have onshore mature fields, which produce at marginal rates, for 80 years or more, which is rare offshore. Production costs require marginal wells to be closed. And the costs and difficulties are geometrically proportional to the water depth. Shallow water fields in Norway can reach an RF of 65%. In Brazil, recovery factors of up to 85% are expected in onshore fields, while modern and highly prolific pre-salt fields are expected to produce 16% of their oil il place. 84% of the oil will remain in the rock.
The alternative is to apply technologies massively, and the sooner they are planned and implemented, the better. Among the possible strategies and lines of action applicable are:
Water and gas management. Optimization of water injection using techniques such as: PWRI (produced water re-injection), IAFP (injection of water above fracture pressure), etc Reduction in well construction cost for infill drilling. Application of well slender architecture with one trip completion. Use of liner conveyed gravel pack for unconsolidadted sandstones. U-well planning and construction. Reduction of area and weight of production units: Use of technologies such as RWI (raw water injection), SSWO (Subsea Separation of Water and Oil), etc This paper aims to make an overview of the applied and applicable technologies for extending the useful life of offshore fields, trying to make viable also for high water depths a philosophy of a recognized mature field operator: "The last field to be explored must be the increase of the recovery factor "
Mero Field: Topsides for Fluids with High GOR and High CO2 Content – How Innovative Solutions Unlock the Addition of Processing Capacity and Subsea Processing to Add Value Generation
Authors: Shiguematsu F. M. , Passarelli F. M. , de Araújo F. B. , de Castro V. F , Favre J. Y. 
Published: October 2023

Abstract
Libra field has reservoir fluids with high GOR and CO2 content which add significant challenges to the development projects. Innovative solutions on topsides were assessed to optimize the process plant, aiming to reduce complexity, footprint, and weight, to allow processing capacity increase, adding value to development projects. This article details the technology selection process, the challenges of implementation with the first successes as well as the obtained gains in comparison with base case solution.
The first large Mero's floating production unit was conceived with processing capacities of 180,000 bpd and 12,000,000 Sm³/d of gas due to reservoir characteristics. It was a challenge to fit it in a VLCC hull size within reasonable CAPEX and lead time. Therefore, technical studies were carried out to optimize Libra topsides, driven by footprint/ weight and power reduction, better operational efficiency, extension of oil production plateau and water injection capacity increase that were successful via implementation of the innovative solutions: increase 1st separation pressure; sea water pre-treatment and gas dehydration optimizations; and addition of an innovative subsea processing system.
The present article compares the first gains obtained by the addition of innovative solutions that modified the original concept of the first large Mero's floating production unit as follow: (1) increase of the first liquid-gas separation stage pressure in the oil treatment plant, that allowed gas compression plant and power demand reduction; (2) significant reduction in gas dehydration plant weight/ footprint and complexity by enabling triethylene glycol as alternative. This technical solution was not applied in Pre-Salt units until that time; (3) designing the interfaces between the floating production unit and the innovative subsea gas processing system will allow future interconnection to extend the oil production plateau, adding value in case technology development success; (4) increase of sea water injection capacity. The implementation of the innovative solutions above summarized is improving the design and operational efficiency of the FPU adding value to the project.
The results obtained by the implementation of innovative solutions in Mero's FPU until this moment are showing the success of conceptual studies evaluation and enabling improvements in processing plant and allowing the inclusion of subsea processing system.
Wireline In-Situ Fluid Property Measurement: A High CO2 Case Study from a Brazilian Pre-Salt Carbonate
Authors: Bittencourt B. T. , Vasconcellos P. B. M. P. , Monteiro V. F. , Bertolini A. , Dantas M. 
Published: October 2023

Abstract
Knowing the characteristics of oil and the presence of contaminants (such as CO2) is essential for the proper evaluation of a petroleum accumulation. This work aimed to verify the accuracy of the oil composition estimates obtained by the In-Situ Fluid Analyzer (IFA) module, from SLB, for different pre-salt oil accumulations in the Santos Basin. A methodology, based on the results of this study, was applied to anticipate the information about the formation fluid characteristics for a wildcat well using the compositional estimates of the IFA module during the logging operation.
RIMS: A Fully Integrated Technology for Long-Term Riser Monitoring
Authors: Albani Yvan , Cavallini Francesco , Girello Enrico , Lazzarin Diego , Massari Giovanni , Novello Marco 
Published: October 2023

Abstract
Nowadays, offshore operators have an increased requirement to reduce the operational risks while performing offshore natural resources exploitation. This, in particular, applies to critical steel catenary risers whose long-term integrity with respect to fatigue and extreme events is key for safe operations: due to their dynamic behavior, risers are one of the most critical assets being subject to severe environmental and operation loads, which shall be studied in detail at the design stage. Given the large number of external actions and the riser complex response, riser engineering is typically affected by several uncertain parameters, therefore an accurate monitoring of its integrity is key to ensure safe operations in the short-term and gain the necessary knowledge in the medium to long-term thus enabling design optimization, asset maintenance and life extension. These considerations place risers monitoring as a central technological theme for the offshore energy industry.
The design and realization of an adequate riser monitoring is a complex activity requiring: i) the deep knowledge of riser physics to support a holistic assessment of the parameters to be monitored, ii) the direct access to modern technologies, as digital twin, to enable the realization of even more efficient and innovative monitoring solutions tailored for the specific projects’ needs. In this context, Saipem has a privileged viewpoint given its long-term experience in rigid riser engineering, construction, and installation (as EPCI contractor responsible for the SURF scope) combined with strong capability in providing integrate, novel and fully customized solutions for underwater assets monitoring through its Sonsub business.
This paper investigates the benefits coming from this integrated approach where the monitoring system is conceived, realized, and installed as an integral part of the related riser and explores the potential advantages linked to the implementation of data interpretation features capable to support riser system integrity analysis along the asset operational life. This paper provides also an overview of the challenges behind riser monitoring systems realization passing through the main development phases: from the initial qualification and engineering phase to the installation and integration testing.
To offer a very pragmatic view on the topic, the paper presents a brief summary of Saipem recent experience in developing and qualifying riser monitoring systems for some Brazilian projects specifically designed for steel catenary riser configurations.