bluuebunny/crossref_metadata_2025_split huggingface dataset:
Thermoplastic Composite Pipes: A Reliable Cost-Effective Solution for Pre-salt
Authors: Barbosa Teofilo , Bastos Renato , De Boer Henk , Rojas-Díaz Ramón 
Published: October 2019

Abstract
Thermoplastic Composite Pipe (TCP) has a solid wall construction constituted from a single polymer material with embedded (melt-fused) fibre reinforcements. It is a disruptive technology where all the advantages for ultra-deep water developments come together: high strength, light weight, corrosion free, low CAPEX, etc. TCP is therefore one of the most promising solutions to overcome the recent failures found on pre-salt fields related to corrosion under high concentrations of H2S and CO2.
However, introducing a new technology on very challenging applications such as deep water production risers, requires careful consideration and mitigation of all technical and project execution risks.
This paper starts presenting a historical review of some of the new technologies applied offshore Brazil over the last 20 years making a parallel with the increasing acceptance of Thermoplastic Composite Pipe in the Brazilian market.
Following the historical review, TCP technology is presented and strategy to enable free hanging catenary systems for ultra-deep water environments discussed.
The basis of the study is a typical offshore Brazil pre-salt field and feasibility of 6" and 8" free hanging TCP risers were assessed. Study was performed in close cooperation with a major operator and an installation contractor in Brazil. Global, installation and local analyses of the TCP Riser system have shown the feasibility of installation as well as operations in a free hanging catenary configuration throughout the 30 years' service life. In 2017, this pre-FEED study was used as basis for a FMECA (Failure mode, Effects and Criticality Analysis). The FMECA exercise was carried out together with a third-party certification body and two major Oil & Gas companies very active in Brazil.
A detailed business case study was performed in order to quantify the potential CAPEX savings that TCP technology can bring compared to the low lazy wave systems currently installed in pre-salt fields, offshore Brazil. Result is that if TCP is adopted as primary technology for Risers&Flowlines, significant savings are expected. Savings comes both from pipe and ancillary's procurement costs since TCP technology enables free hanging catenary configuration, avoiding purchase of expensive buoyancy modules.
The outcome of this work lead to a qualification program currently being sponsored by one major operator active in Brazil. Technology Roadmap was established in phases being the ultimate goal the qualification of pre-salt 8.0in production lines. Reasons for adopting this qualification strategy is presented. The qualification is driven by DNV-ST-F-119, a dedicated standard for TCP design and qualification.
Optimization of CO-WAG and Calcite Scale Management in Pre-Salt Carbonate Reservoirs
Authors: Rodrigues Hydra , Mackay Eric , Arnold Daniel , Silva Duarte 
Published: October 2019

Abstract
CO2-WAG (Water-Alternating-Gas) has been applied in offshore Brazilian oilfields to improve recovery rates and mitigate the environmental impact that venting produced CO2 would bring. Although CO2 is highly miscible in oil under these reservoirs conditions, this gas is also extremely mobile, and its speciation in the aqueous phase drives reactions with carbonates that can cause severe inorganic scaling problems in production systems. It is crucial, therefore, to effectively design CO2-WAG operations for mobility control and, consequently, enhance reservoir performance, CO2 utilization and flow assurance.
This paper addresses the design optimization of coupled CO2-EOR and storage operations applied to the Brazilian Pre-salt offshore context (reservoir properties, infrastructure, regulatory framework and economic characteristics), examining the trade-offs of project profitability, CO2 utilization and calcite scale risk. Several compositional simulations of miscible WAG scenarios were performed and key design parameters were optimized using statistical sampling and evolutionary algorithms. Aqueous and mineral reactions were included in the calculations, allowing us to quantify the calcite mass that can potentially deposit in the perforations and production system.
The results showed how optimizing WAG operations can significantly improve the economics and the scale management of oil production from carbonate reservoirs. The optimal WAG design greatly increased incremental NPV per volume of CO2 stored and reduced calcite scale risk by simply rearranging the WAG slugs in a tapered manner.
Here we demonstrate that this methodology can be used to determine how to recycle CO2 in a given field for better economics and lower carbon footprint, doing so without triggering calcite mineral deposition to the point of permanent jeopardy of production wells and facilities operability. Therefore, the workflow integrates critical challenges that are correlated, yet often addressed independently, supporting the complex decision-making of CO2-EOR operational design in carbonate reservoirs.
The Use of Drones and Deep Learning to Identify Igneous Rocks and Fractures
Authors: Oliveira Maria José Resende , Savastano Vitor , Matos Gabriel , Schmitt Renata Silva , Valente Valente Castro , Araújo Mário Neto , Inocêncio Leonardo Campos 
Published: October 2019

Abstract
Igneous (or magmatic) rocks may be critical elements in the petroleum systems. They may be related with generation, migration and trapping of oil and gas and also generate hydrothermal processes that can affect the reservoirs. In Campos and Santos basins, they occur as volcanic and intrusive bodies, affecting the pre-, intra- and post-salt sequences. Associated with fractures and faults, igneous intrusives were emplaced during reactivation of preexisting discontinuities or weakness zones, although they also cross cut them. In the continental area, adjacent to the Campos and Santos basins, intrusive igneous bodies crop out as dykes, sills and stocks. The area selected for this study is the "Pontal do Atalaia", in the city of Arraial do Cabo (RJ). The use of drone images allowed to identify the structural framework of the igneous bodies and fractures patterns associated with them. By developing tools of deep learning, it was possible to analyze the fractures and compare the results with visual interpretation. In both cases, the results indicate the predominance of fractures along roughly N-S and E-W trends. The outcomes allow the comparison and correlation to the offshore geological features to better understand the role of the igneous rocks and fractures in the tectonic evolution of Campos and Santos basins.
Case Study: Brazil Deepwater, Pre-Salt – Successful Intermediate Casing Shoe Squeeze Using Microcement
Authors: Freitas Rodrigo , Rossi Lucas , Gregatti Ana Carolina , Moretti Fabricio , Pagani Leonardo 
Published: October 2019

Abstract
Drilling the Marlim field at the Campos Basin has shown quite a challenge in the last few years. The field is located 110 km from Sao Tome cape at the north coast of Rio de Janeiro State, at the Campos Basin, have started commercial exploration for in 1991 and with water depths varying between 600 to 1000 m. The reservoir is composed of sandstone formation and just recently, an exploratory campaign at the field surroundings.
The project of the well in the Marlim field was always complex with eight phases predicted. For the phase 4, due to the narrow fracture and pore pressure window, and also the high number of potential flow zones to be isolated, the client has decided to run a 13 5/8" stage collar in order to isolate all sandstone formations and cement the combined 14" × 13 5/8" Intermediate Casing. The idea of using the stage collar was to isolate the water holder formation, Carapebus Lambrusco sandstone, located just at the stage collar depth and then open the stage collar and cement the remaining sandstone all the way to the last water holder formation, Carapebus Marlim sandstone. The other objective of this job was to provide enough integrity to the shoe, set at the salt formation, in order to allow drilling the subsequent 14 ¾"open hole all the way to the carbonate formation.
After drilled the 16 1/2" open hole of an offshore well, the intermediate casing had to be cemented with a two stage collar with sub sea release plug set, to bring the top of cement higher and isolate upper formation. Due to operational issues, there was a failure in the first stage cement job, which was confirmed with a failed formation integrity test - necessary 13.0 lb/gal to drill ahead the subsequent 14 3/4" phase.
To solve the issue, to achieve formation integrity test of 13 lb/gal, it was necessary to perform a Casing Shoe Squeeze Cement job. The problem is that historically those intervals experience very narrow gaps, which means low injectivity. After several failed attempts with conventional cement, a novel technology was used combining microcement with a strong fluid loss control that could enable the cement to be injected into narrow gaps. The use of microcement alone provides rapid compressive strength development, very low rheology and combining with a fluid loss additive enables to provide the system with very high injectivity
Asa Branca Offshore Wind Farm Project – Main Technical Aspects
Authors: Wey Acácio 
Published: October 2019

Abstract
The plans to develop the ASA BRANCA OFFSHORE WINDPOWER PROJECT were envisioned a long time ago, by 2001, after a great drought in Brazil, as reported in the Historical Scenario of this article, aiming at providing the National Grid with larger clean energy sources by means of offshore wind power plants. Its initial phase shall start by 2025 with 720 MW of installed capacity on the Brazilian Northeast coast. Today, it represents a challenging project since its implementation will be the largest pioneer offshore generation not only in Brazil, but also in the southern hemisphere at the tropical environment near the equator. The feasibility studies indicate the higher capacity factor of this Project that accrues from the known trade winds on this region blowing steadily toward the equator from the southeast.
The Project presented herein shall be the first phase of a much larger Offshore Wind Farm development that EÓLICA BRASIL has defined and presented to the Brazilian Authorities. This Phase-I has received permits to be installed at the sea near shore in the Municipality of Amontada, in an area that spans 15 km along the coast of Ceará State and at about 9 to 18 km distance of from the seashore.
In this region, there are more than 6 GW of onshore wind power plants installed or planed along the coasts of the Northeast Region at Ceará and Rio Grande do Norte States, distributed in hundreds of small and medium onshore generations very near the seashore. The successful operational experience of those projects is a significant indication of the unexplored offshore windpower potential available on this Brazilian coastal region, so that it is included among the most promising regions in the world to produce bulk clean power, especially considering huge offshore windpower plants that will certainly be one of the main Brazilian contributions to reduce the risks from global warming. World's biggest companies, from hi-tech firms to large banks, are bracing for prospect that climate change could substantially affect their bottom lines yet within the next decade due to impacts that will be faced as the planet warms. Early estimates suggest that trillions of dollars may ultimately be at stake.
The development of such enormous offshore potential of renewable energy, assured by existing both Brazilian legislation and official regulations, became technical and economic feasible in Brazil by applying the new conception of offshore wind turbine generators (WTGs) with unit ratings larger than 10 MW propelled by wind speeds faster than 10m/sec.
This paper presents the main technical characteristics of the conceptual design of this pioneer Project in Brazil, including the basics of planning and feasibility studies as well as the foreseen scenarios for national power market for offshore wind generation on the horizon of the next decade (2021-2030).
Understanding the Behavior of Surface Hardness Hard Spots of Plate and Pipe :Extensive Test Program
Authors: Singh Kathayat Tribhuwan , Hill Rick , Thakor Piyush , Kumar Goyal Rajesh , Singh Ankit 
Published: October 2019

Abstract
Recent use of thick wall pipelines for the transmission of extreme sour hydrocar bons in deep and ultra- deep water has required the confirmation of resistance to environmental cracking. This paper presents a comprehensive test program conducted on 30 inch outside diameter and 38.7 mm wall thickness, ISO 3183 L415MS / L415MO PSL2 line pipe to establish the contribution of plate and pipe properties and process parameters on the environmental cracking resistance.
The JCOE forming technology was used to prepare the test pipes for evaluating the influence of isolated surface hardness zones on the initiation and propagation of Hydrogen Induced Cracking (HIC) and Sulfide Stress Corrosion Cracking (SSCC). Detailed technical requirements for plate supply included but was not limited to the development of alloy design, steel melting and continuous casting parameters as well as plate rolling and accelerated cooling process control limits.
The test program covered the contribution of various stages of pipe production such as forming, welding, and mechanical cold expansion, on fracture toughness (KIC, KISSC and CTOD), HIC and SSCC resistance. The pipe was tested in the as-manufactured, aged, and aged+1% strained conditions. Pipe dimension conformance was verified using the Automatic Pipe Dimension Measurement System (APDMS).
The reliability of eddy current inspection for the detection of isolated hard zones was included in the program.
Wet Christmas Tree Interface for Depressurizing Underwater Flowlines
Authors: Beppler Raphael Veloso , Camargo Ricardo Marques de Toledo , Cardoso Carlos Alberto Bandeira Ribeiro , Nascimento Everton da Rocha , Pimentel Daniel Monteiro , Rodrigues Roberto , Soares Renato de Freitas 
Published: October 2019

Abstract
Oil and gas flowlines plugging due to hydrate formation is one of the main reasons for production losses in deep water production systems. Therefore, several hydrate prevention and mitigation techniques have been constantly developed and applied by industry.
Regarding hydrate dissociation techniques, efforts focus on avoiding the use of naval resources, such as workover rigs or special vessels, because of the high cost involved and, very often, the poor readiness.
This work presents an ROV connection device, installed in the Production Adapter Base / Tubing Head Spool (PAB / THS) of a Wet Christmas Tree (WCT), which allows coupling a local system of fluids depressurizing and handling, eliminating the need of a classified vessel to handle hydrocarbons.
Besides allowing faster hydrate removal in subsea flowlines, the proposed method do not require any technological development since it consists of the integrated use of subsea devices and tools commonly used in the offshore industry.
Replacing Fossil Fuels by Wind Power in Energy Supply to Offshore Oil&Gas Exploration and Production Activities – Possibilities for Brazil
Authors: Schaffel Silvia Blajberg , Westin Fernanda Fortes , Hernandez Omar Mauricio , La Rovere Emilio Lèbre 
Published: October 2019

Abstract
GHG emissions will create constraints for the oil and gas industry. Meeting world energy needs with lower GHG emissions is its big challenge in the current context of energy transition. The possibility to use renewable power for the energy supply to offshore O&G E&P activities, thus reducing its emissions is discussed in this paper. In Brazil, there are today three E&P environments: onshore, conventional offshore and pre-salt. In conventional offshore, the reuse of fixed platforms as structures for offshore wind development is an opportunity to be assessed. In the pre-salt, as FPSOs demands are energy intensive, the next generation of offshore wind power floating turbines might be employed. This paper presents some examples of trends in using offshore wind power, highlighting the electrification of O&G platforms associated with GHG reduction. We are in the early days of offshore wind power in Brazil and the promising outlook is not for the short-term, but for the Pre-Salt country, in the current context of energy transition, it will become increasingly important to assess and implement the generation of offshore wind power.
Methodology to a Feasibility Study to Implement an Oil/Water Subsea Separation
Authors: Vigano Guilherme Cosme 
Published: October 2019

Abstract
Currently, low oil prices pose a challenge to the financial state of the industry. Therefore, it is very important that companies optimize costs while maintaining or even increasing oil production. At the same time, with oil production declining due high water cuts and facility volume limitations in an offshore production system, it is necessary to look for solutions in order to maintain economic viability by increasing oil recovery in mature reservoirs. Among some alternatives, the subsea separator represents a good prospect for dealing with these challenges.
This paper aims to describe a methodology to perform the technical feasibility study of deploying an Oil/Water Subsea Separator in Brazilian Offshore Field. The technical results were then used as part of an economic analysis which is outside the scope of the present paper.
The study is comprised four wells that are linked to the manifold and the subsea separator. In the subsea separator, 70% of the produced water is separated and reinjected in a disposal well. Hence, the fluids which remains (oil, gas and 30% of water) flows up to the platform. Since this reinjected water volume is not flowing to the platform anymore, more fluid can be processed, allowing the wells to operate on larger potentials resulting in an increased cumulative oil production to the field. Computational simulation approach was followed by using the pore flow simulation, flow assurance simulation and a coupler that integrates both of these.
Severe Slugging Mitigation in an S-Shape Pipeline-Riser System With a Venturi for Increased Production and Recovery
Authors: Inok Joseph , Lao Liyun , Cao Yi , Whidborne James F. 
Published: October 2019

Abstract
Severe slugging is a cyclic flow regime which causes intermittent delivery of oil and gas which usually leads to flow separator flooding, production reduction, platform trips and plant shutdown. This paper presents a novel method for severe slugging mitigation. It describes the use of a Venturi for the improvement of system stability, increase in production and recovery.
A Venturi is coupled to the pipeline-riser system upstream of the choke valve before the topside test separator for severe slug mitigation. Experiments were carried out in a 2″ pipeline-riser system which comprises of a 40 m long horizontal pipe connected to a 10.23 m high S-shape riser followed by a 5.2 m horizontal topside section. The effects of Venturi on severe slugging were investigated, gas perturbation method was used to analyse the effects of Venturi on the stability of the system, and the traditional choking technique and Hopf bifurcation technique were combined and used to investigate the stability and production increase performance of the pipeline-riser with Venturi applied.
Experimental results show that with the Venturi applied, the system achieves stability quicker than without the Venturi in the pipeline-riser and reduced the pressure fluctuation range by 57 %. In addition, combining the Venturi with the choke valve to choke the pipeline-riser (bifurcation study) stabilised the system at higher valve opening and lower pressure compared to choking the pipeline-riser with the choke valve only. For the case studied (Vsl = 0.25 m/s and Vsg = 0.37 m/s) bifurcation (critical valve opening) occurred at 18 % valve opening and average riser base pressure value of 2.8 barg for the plain riser. However, with Venturi applied bifurcation occurred at a larger valve opening of 21% and a lower average riser base pressure value of 2.5 barg. The low loss of energy due to the gradual change in geometry of the Venturi may account for its ability to achieve stability at a lower riser base pressure. Thus, Venturi increased the valve opening by 17% and reduced the riser base pressure by 11%. These in practice translate to an increase in oil and gas production.
This is a cost-effective severe slug mitigation method, its deployment at the topside is an additional advantage when compared with other methods that require subsea deployment. The increase in brown fields due to diminishing reserves of oil from reservoirs have made oil recovery very vital. This technique will help to extend the operational life of a reservoir, thus enhancing oil recovery and flow assurance.
Impact of Rock Aging Time on the Initial Wettability of Minerals and Analogue Rocks Using Pre-Salt Fluids Under Reservoir Conditions
Authors: Drexler Santiago , Hoerlle Fernanda Oliveira , Silveira Thais M. G. , Cavadas Leandro A. , Couto Paulo 
Published: October 2019

Abstract
Wettability is an important property in reservoir characterization. For the heterogeneous carbonate reservoirs in the Brazilian Pre-Salt, parameters that represent wettability are needed to obtain improved reservoir models. In this work, we applied contact angle measurements to analyze rock-fluid interactions between synthetic brine, crude oil from a Pre-Salt field and rocks and minerals with similar characteristics to the Pre-Salt formations. We studied the effects of aging time on different solid substrates. We found that, even though unaged quartz showed greater interaction with the high basic number oil than carbonates, it re mained water-wet for different aging times. On the other hand, calcite and coquinas had increasing contact angles with aging times and were strongly oil-wet after 30 days aging. This evidences that the interactions between acid compounds in the oil and basic sites in the substrate are strong enough to disrupt the water film after aging for 30 days. Therefore, under the Pre-Salt conditions studied in this work, these carbonate rocks and minerals should be considered as preferentially oil-wet.