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Collaborating Authors
Results
Mero Field: Integrated Development, Challenges and Innovations
Neder, Ana Luiza (Petrobras, Rio de Janeiro, RJ, Brasil) | Calôba, Guilherme Marques (Petrobras, Rio de Janeiro, RJ, Brasil) | da Silva, Letícia Soares (Petrobras, Rio de Janeiro, RJ, Brasil) | Hayashi, Mauro Yuji (Petrobras, Rio de Janeiro, RJ, Brasil)
Abstract Mero field is among the biggest hydrocarbon discoveries in Brazilian pre-salt province and turned out to be a giant and high productivity reservoir. However, it has characteristics such as thick and heterogeneous carbonate reservoir, high reservoir pressures, high Gas-Oil Ratio (GOR), high CO2 content and presence of H2S that makes exploration and production challenging, as it requires specialized equipment and advanced technologies. An important pillar for the field, integrated development, is the Project Based Technology Development. Mero leverages existing or innovative technologies and aims to identify and close technology gaps in an integrated approach to maximize project value and increase its attractiveness. One of the primary challenges in highly complex reservoir, such as Mero, is deep reservoir understanding, and a robust drainage plan strategy. To mitigate all the main risks that could affect the Project results, Data Acquisition in the Production Phase must be planned and executed to minimize impacts on the Project deployment, obtain the information in time for optimizing the Project, and maximize the production and results at every moment. To maximize oil recovery and obtain a sustainable development, Mero Project considers the reinjection of gas and CO2 through alternating water and gas injection method (WAG) in all injector wells. A variety of offshore technologies were pushed beyond its previous limits, establishing industry "firsts", which have enabled an accelerated approval process and the development of the next production systems. To overcome all the technical and economic challenges, the Consortium created an integrated cooperative environment. As a result of the big integration between Consortium members and the supply chain companies involved, Mero Project is conceived through the application of several cutting-edge technologies, enabling the recovery of this large reserve with competitive break-even and robust carbon storage in the reservoir. Those practices were key to deploy two early production systems (FPSO Pioneiro de Libra) and one definitive system (FPSO Guanabara) – currently the higher FPSO in production in Brazil. The total field production is around 230.000 bpd and there are three others FPSOs to be deployed in the coming years. A compiled of practices applied to overcome the Mero field challenges and maximize the project's results. Those practices came from all the technical disciplines, such as Reservoir, Wells, Subsea, FPSO and Operations, as well as Compliance, HSE and management of the Production Sharing Contract. Some Technologies developed include but are not limited to Permanent Reservoir Monitoring (PRM), Cargo Transfer Vessel (CTV) and HISEP®, a Petrobras patented technology specifically designed to deal with high CO2 and gas content in Mero Reservoir.
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Santos Basin > Libra Block > Mero Field (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Santos Basin > Libra Block > Libra Field > Guaratiba Formation (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Santos Basin > Block BM-S-11 > Libra Field > Guaratiba Formation (0.99)
- (2 more...)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Gas-injection methods (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Reservoir Description and Dynamics > Fluid Characterization (1.00)
- (4 more...)
Challenges on the Governance of Libra PSC
Francisco, F. F. (Libra Project, PETROBRAS – Petroleo Brasileiro S.A, Rio de Janeiro, Brazil) | Flach, E. B. (Libra Project, PETROBRAS – Petroleo Brasileiro S.A, Rio de Janeiro, Brazil) | Amendola, A. F. (Libra Project, PETROBRAS – Petroleo Brasileiro S.A, Rio de Janeiro, Brazil) | Rodrigues, F. M. (Libra Project, PETROBRAS – Petroleo Brasileiro S.A, Rio de Janeiro, Brazil) | Santos, G. S. S. (Federal University of Rio de Janeiro)
Abstract The Governance of a Production Sharing Contract was one of the challenges for Libra Project. In this 10 anniversary of first round bidding in Brazil there are a lot of celebrate. Libra Project created a robust governance project. The aim of this paper is to show how this governance process supported Libra Project during these 10 years. It begins with an overview of Libra PSC, after it discuss about all challenges in the development strategy, remarking the new technologies created by Libra team. It brings the importance of the Libra Governance and cost oil recovery process, and finishes discussing Libra new challenges that are production and greenhouse emissions.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > South America Government > Brazil Government (0.33)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Santos Basin > Libra Block > Mero Field (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Santos Basin > Libra Block > Libra Field > Guaratiba Formation (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Santos Basin > Block BM-S-11 > Libra Field > Guaratiba Formation (0.99)
- (2 more...)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- Production and Well Operations (1.00)
- (7 more...)
Abstract Energy companies need access to reliable and continuous sand production information to improve their understanding of sand-producing wells. Removing sand directly downstream of the wellhead while also monitoring the separated sand in real-time enables quantified sand data to be transformed into valuable insights on the well production and provides an understanding of reservoir behaviour. With the increase in the deployment of Normally Unmanned Installation (NUI) and satellite platforms by energy companies, it is becoming increasingly important to have remotely operated systems that traditionally have been manually operated. This paper introduces a system for optimizing production through remote monitoring and quantifying offshore sand production in an "industry-first" case study. The operation was conducted in 2022 on a NUI in the North Sea. The asset was anticipated to produce more than 4 000kg of clay/proppant mix solids with the potential for producing Benzene and Naturally Occurring Radioactive Material (NORM). Typically, wells producing solids are kept closed in, but in this case, a desander with a closed-loop system was utilized to enable production and avoid personnel exposure. Project results included stable production, remote monitoring of sand production, POB (Personnel On Board) and emissions reduction compared to a conventional operation while preserving the operator's process safety requirements. With continuous measurement and solids removal, the operator could continue operations without personnel onboard. The desander provided data directly to production engineers. It gave them access to information that enabled fact-based decisions, ensuring a holistic methodology for production and integrity for the asset without needing personnel offshore. New ground breaking technology is shared in this paper to help more energy operators manage sand-producing wells. With the increased focus on POB, remote solutions are part of the solution. This paper shares a project with documented success.
- Europe > North Sea (0.34)
- Europe > United Kingdom > North Sea (0.25)
- Europe > Norway > North Sea (0.25)
- (2 more...)
- Well Completion > Sand Control (1.00)
- Well Completion > Completion Installation and Operations (1.00)
- Reservoir Description and Dynamics (1.00)
- (9 more...)
- North America > Canada (1.00)
- Europe (1.00)
- Asia > China (1.00)
- (5 more...)
- Personal > Honors (1.00)
- Overview (1.00)
- Instructional Material > Course Syllabus & Notes (1.00)
- (2 more...)
- Geology > Rock Type (1.00)
- Geology > Petroleum Play Type > Unconventional Play (1.00)
- Geology > Geological Subdiscipline > Geomechanics (0.67)
- (3 more...)
- Materials > Metals & Mining (1.00)
- Law (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- (7 more...)
- North America > United States > Oklahoma > Arkoma Basin > Cana Woodford Shale Formation (0.99)
- North America > United States > Arkansas > Arkoma Basin > Cana Woodford Shale Formation (0.99)
- Africa > Angola > South Atlantic Ocean > Lower Congo Basin > Block 17 > Pazflor Fields > Pazflor Field (0.98)
- (4 more...)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Geologic modeling (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- (18 more...)
Boosting To Boosting: A New Approach To Enhance, Support And Maximize Subsea Processing And Boosting Applications
Roberto, Marcello Augustus Ramos (Petrobras Petróleo Brasileiro S.A) | E Silva, Jean Carlos Dias (Petrobras Petróleo Brasileiro S.A) | Koelln, Herbert Prince (Petrobras Petróleo Brasileiro S.A) | Bernardes, Alan Carlos (Petrobras Petróleo Brasileiro S.A) | Albuquerque, Fabio Alves (Petrobras Petróleo Brasileiro S.A) | Paternost, Guilherme Miranda (Petrobras Petróleo Brasileiro S.A) | De Oliveira, Ana Margarida (Petrobras Petróleo Brasileiro S.A) | Xavier, Gilberto Magalhães (Petrobras Petróleo Brasileiro S.A) | Da Silva, Jurandir Antônio Gomes (Petrobras Petróleo Brasileiro S.A) | Da Costa, Otavio Cardoso (Petrobras Petróleo Brasileiro S.A)
Abstract Over the last 20 years subsea processing and boosting (P&B) technologies have supported and pushed forward the offshore oil and gas production, maximizing field production and recovery factor. Although those technologies achieved remarkable success, P&B is still not a heavy-weight business, despite Operators considering it adds great value. Therefore, to enhance and maximize P&B applications, a task force was created to identify the main hurdles, showstoppers and barriers, as well as to establish a robust process, methods and procedures related, including O&G Operators and Suppliers point of views, internal standards and international codes analysis. Afterwards, a critical analysis was made, more than ten initiatives were prioritized, and a Program named Bosting to Boosting (B2B) was structured. This paper will present all initiatives have been carried out in B2B and the main results for subsea projects.
- South America > Brazil (0.94)
- North America > United States > Texas (0.47)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Block P-36 > Roncador Field > Maastrichtian Formation (0.99)
- South America > Brazil > Espírito Santo > Espirito Santo Basin (0.99)
- South America > Brazil > Campos Basin (0.99)
- Reservoir Description and Dynamics (1.00)
- Production and Well Operations > Artificial Lift Systems > Hydraulic and jet pumps (1.00)
- Management > Asset and Portfolio Management (1.00)
- (3 more...)
Design for preventing or minimizing the effects of accidents is termed accidental limit states (ALS) design and is characterized by preventing/minimizing loss of life, environmental damage, and loss of the structure. Collision, grounding, dropped objects, explosion, and fire are traditional accident categories.
- South America > Brazil (1.00)
- Oceania > Australia (1.00)
- North America > Canada (1.00)
- (11 more...)
- Summary/Review (1.00)
- Research Report > New Finding (1.00)
- Research Report > Experimental Study (1.00)
- (3 more...)
- Geology > Mineral (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Sedimentary Geology > Depositional Environment (0.67)
- Geology > Structural Geology > Tectonics > Plate Tectonics (0.67)
- Transportation > Marine (1.00)
- Transportation > Infrastructure & Services (1.00)
- Transportation > Ground (1.00)
- (36 more...)
- South America > Brazil > Campos Basin (0.99)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Viosca Knoll > Block 786 > Petronius Field (0.99)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Mississippi Canyon > Block 392 > Appomattox Field (0.99)
- (58 more...)
"In offshore and coastal engineering, metocean refers to the syllabic abbreviation of meteorology and (physical) oceanography" (Wikipedia). Metocean research covers dynamics of the oceaninterface environments: the air-sea surface, atmospheric boundary layer, upper ocean, the sea bed within the wavelength proximity (~100 m for wind-generated waves), and coastal areas. Metocean disciplines broadly comprise maritime engineering, marine meteorology, wave forecast, operational oceanography, oceanic climate, sediment transport, coastal morphology, and specialised technological disciplines for in-situ and remote sensing observations. Metocean applications incorporate offshore, coastal and Arctic engineering; navigation, shipping and naval architecture; marine search and rescue; environmental instrumentation, among others. Often, both for design and operational purposes the ISSC community is interested in Metocean Extremes which include extreme conditions (such as extreme tropical or extra-tropical cyclones), extreme events (such as rogue waves) and extreme environments (such as Marginal Ice Zone, MIZ). Certain Metocean conditions appear extreme, depending on applications (e.g.
- Europe > United Kingdom > England (1.00)
- Asia > Middle East > Saudi Arabia (1.00)
- Asia > Japan (1.00)
- (16 more...)
- Summary/Review (1.00)
- Research Report > New Finding (1.00)
- Research Report > Experimental Study (1.00)
- (3 more...)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Sedimentary Geology > Depositional Environment (0.67)
- Geophysics > Electromagnetic Surveying (0.65)
- Geophysics > Seismic Surveying > Seismic Modeling (0.45)
- Transportation > Passenger (1.00)
- Transportation > Marine (1.00)
- Transportation > Infrastructure & Services (1.00)
- (36 more...)
- Europe > Denmark > North Sea > Danish Sector > Central Graben > Block 5504/12 > Tyra Field (0.99)
- Europe > Denmark > North Sea > Danish Sector > Central Graben > Block 5504/11 > Tyra Field (0.99)
- North America > United States > Colorado > Ice Field (0.98)
- (18 more...)
- Well Drilling > Well Planning > Trajectory design (1.00)
- Well Drilling > Drillstring Design > Drill pipe selection (1.00)
- Well Drilling > Drilling Operations (1.00)
- (53 more...)
This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper OTC 31943, “Introduction to New Technology Applications, Data-Acquisition Capabilities, and Features of the All-Electric Boosting Control System,” by Kjetil Bergtun, Carsten Mahler, and Trond Melheim, OneSubsea. The paper has not been peer reviewed. Copyright 2022 Offshore Technology Conference. Reproduced by permission. The complete paper describes an all-electric system (AES) and how its implementation will simplify operating processes, reduce topside and subsea weight and cost, and lower the risk of hazardous fluids escaping into the ocean. The authors place special focus on the electrical actuators that were introduced in this project as well as the challenges faced during project execution. Vigdis Field The Vigdis field was discovered in 1986 between the Snorre, Statfjord, and Gullfaks fields in the Tampen area of the North Sea. The development consisted of seven subsea templates and two satellite wells producing to the Snorre A (SNA) facility, which contains a dedicated processing module for Vigdis. In 2002 the plan for development and operation of the Vigdis extension was approved. An unprocessed wellstream is transported from Vigdis to the Snorre A platform by two flowlines. Stabilized oil is transported by pipeline from Snorre A to Gullfaks A for storage and export (offloading). The second platform (SNB) in the Snorre field is 11 km north of SNA. The Snorre field is approximately 130 km from the Norwegian coast, nearly at the same latitude as Florø. When the Vigdis field came onstream in 1997, recoverable resources were estimated at 200 million bbl of oil. The field has now produced 394 million bbl, and recoverable resources have been increased to 455 million bbl of oil. Production from the field was limited by the capacity of the production lines and pressure drop across the topside chokes. Reservoir deliverability was limited by low reservoir pressure in some parts of the field, together with increasing water cut, leading to reduced energy into the system, which in turn caused dropping wellhead pressures.
- Europe > Norway > North Sea > Northern North Sea > East Shetland Basin > Tampen Area (0.99)
- Europe > Norway > North Sea > Northern North Sea > East Shetland Basin > PL 089 > Block 34/7 > Vigdis Field > Vigdis Øst Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > East Shetland Basin > PL 089 > Block 34/7 > Vigdis Field > Vigdis Nordøst Formation (0.99)
- (26 more...)
- Reservoir Description and Dynamics (1.00)
- Production and Well Operations (1.00)
- Facilities Design, Construction and Operation > Offshore Facilities and Subsea Systems > Subsea processing (0.71)
- (2 more...)
Project Execution of Industry First 20,000-psi Subsea Production System
Pollak, Joshua Brian (Schlumberger) | Pathak, Parth Dilip (Schlumberger) | Weaver, Clint David (Schlumberger) | Gaydos, Stephen Erek (Schlumberger) | Stevens, James Edward (Schlumberger) | Katsounas, Nicholas Paul (Schlumberger) | Penuela, Diego Alejandro (Schlumberger) | Baptista, Alessandro (Schlumberger) | Kaleemullah, Hunnain (Schlumberger) | Watne, Karl Johan (Schlumberger)
Abstract High-pressure high-temperature (HPHT) oil fields in the Gulf of Mexico demand upstream subsea production system (SPS) equipment such as trees, connectors, and manifolds rated for 20-ksi or 400°F. This paper covers the project execution of production equipment for the world's first developed 20-ksi subsea field. This paper includes introduction of new technologies, digitalization efforts, and challenges encountered during the development, manufacturing, and factory testing of this equipment. The development phase of the project began as a multi-year joint venture between OEM and energy companies. This phase included API qualifications and design of core components to industry guidelines such as API 17TR8. Digital analysis tools such as computer-aided design and 3D modeling and tolerancing (CAD and CATS), structural and fatigue analysis using finite element methods (FEA), simulated assembly and operation of equipment in a virtual involvement, and integrated multiplatform optimization software were leveraged for rapid final product development with minimal need for physical testing. To push design ratings to HPHT levels, it was necessary to implement new patented technologies into the design such as couplers, seals, tooling, and lockdowns. The equipment-build phase included upgrading involved plants to state-of-the-art manufacturing and testing facilities. New processes were developed such as using custom fastener pre-load equipment, ultrasonic inspection methods, virtual-build simulations, and new high-pressure test cells with automated remote monitoring and testing capabilities. Subsea deployment of this equipment is planned for 2023. Production systems rated to 20-ksi were built and tested for the first time. New technologies and processes were successfully integrated and validated in an overall assembly. Higher capacity systems introduced new failure modes. The general strategy for HPHT component design is to leverage existing, lower capacity designs but to make the geometry bulkier and the material stronger. A second strategy for design is to reduce the overall loads by reducing pressurized areas, pressure balancing, and offsetting weights. Both approaches lead to new challenges such as weight management, material failures, material sourcing difficulties, seal failures, size restrictions, industry requirement interpretations, cost requirements, assembly complexity, and safety considerations. Development of equipment for 20-ksi fields can be completed in a safe and sustainable manner. The paper presents challenges faced at each stage of project execution and solutions to those challenges. Further, the paper showcases new patented technologies and processes introduced into the system.
- Reservoir Description and Dynamics (1.00)
- Production and Well Operations (1.00)
- Management > Strategic Planning and Management > Project management (1.00)
- (2 more...)
Abstract The objective of this paper is to explore the benefits of using the Interactive Epoch-Era Analysis (IEEA) methodology for evaluating architectural changes in a tradespace exploration study. A subsea tieback offshore Brazil was used to investigate this premise from a full field development perspective. An automated concept exploration tool is employed. It applies meta-heuristics to generate different offshore facilities concepts with varying building blocks. The interaction between reservoir behavior and facilities design is accounted for in each concept differently. These concepts are ranked in terms of economic performance indicators, and each run with a given set of boundary conditions covers what is called an Epoch. This process is iterated for the whole life of field with a set of different commercial boundary conditions generating what is called an Era. The whole data set is evaluated in an interactive platform thru the Humans-In-the-Loop (HIL) process. Model-Based Systems Engineering (MBSE) is being employed successfully in other engineering fields such as the aerospace and automotive industries. While digital tools have been identified as a potential key contributor to the future of O&G performance and further cost reductions, that is yet to be shown. This work intends to provide backing for that argument in one potential application during early concept phases by showing that quick assessments following an MBSE approach may be carried out, once significant effort has been put into proper development, verification and validation (V&V) of such digital tools. SE provides a rigorous and proven method of dealing with complex systems that is highly applicable to offshore field developments. MBSE is the current State-of-the-Art for capital intensive projects such as space exploration spacecrafts and rovers. Learning from successful use cases and applying these methodologies in the development of digital technologies may provide a new set of tools in the belt of operators.
- South America > Brazil (0.34)
- North America > United States (0.28)