FPSO 4.0: Powering Deepwater Production and Optimizing the Lifecycle Performance of Offshore Rotating Equipment Packages

Sehgal, Chirag; Glenn, K. McConell

doi:10.2118/197843-ms

Cited by 3 publications

(1 citation statement)

References 3 publications

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“…FPSOs have the highest invest-on yield compared to other platforms, being particularly effective in deep water and ultradeep water as they can be relocated whenever a reservoir is no longer profitable. Generally, current publications involve process design solutions (e.g., Gyllenhammar et al, 2017;Cho et al, 2018), optimization of topside layout modules (e.g., Ku et al, 2014b), topside systems (e.g., Sehgal and Khan, 2020;Reis and Gallo, 2018), or oilfield and well assignment with oil production (e.g., Gupta and Grossmann, 2012;Moolya et al, 2022), and inventory routing (e.g., Assis et al, 2021). Following Kim et al (2017), there are different ways to arrange equipment in an FPSO topside, since owners can make several operational requirements due to different philosophies and site characteristics.…”

Section: State Of the Art And Reviewmentioning

confidence: 99%

Novel Topside and Subsea Production Optimization, Operational Scheduling, and a Generic Plantwide MPC for Process Systems Control and Production Maximization: Oil, Gas, Water and Utilities Decision-Making with Offloading to Supply Chains and Sustainability

Balbino Barbosa Filho,

Farenzena,

Trierweiler

2024

Preprint

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The main challenges in oil platforms are how to define optimal setpoints and decision-making for controlling variables due to many existing dynamical production uncertainties while conceding safe operation and minimizing discharge to sea and atmosphere without killing plantwide inventory. A novel scheduling model to optimize the whole essential units of an oil platform production gathering topside and subsea variables is disclosed. A proper topside and subsea scheduling model enables and creates harmony between optimal production, supply chain, costs, and market dynamics, satisfying demands, environmental and operations constraints leading to stability. The interest of the present research lies in determining the optimal topside and subsea operational settings and decision-making, establishing maximum E&P performance and production control setpoints while predicting and manipulating reservoir lifespan and its revitalization. This objective is attained through a novel multiperiod large-scale model for the planning and operational production scheduling and model predictive control (MPC) in oil platforms complying with sustainability, profitability, platform design capacities, and offloading of oil and gas to supply chains or to pipeline exportation. The present model details heat and mass transfer, PVT, flow profiles along a planning horizon and can be used to any oil platform since comprises all the essential unit operations for oil, gas, CO2, H2S and water. The model maximizes the total oil production over any planning horizon. The model is versatile, and decision-making can be either linear or nonlinear but rather a MILP or LP as best choice on optimizing large-scale systems. If the model is applied with auto rescheduling on site within variable hours or minutes, it becomes a real-time optimization schedule approach. Due to its high-velocity performance and robustness, a novel multi-objective function strategy, acting as an LP generic plantwide MPC with industrial scope to maximize production while controlling the process is presented, and as an example is here used to control slug flow to avoid equipment trips and inventory instability, at the same time production is maximized. The output from the decision-making was compared to actual plant data, and the results proved compliance to the design capacity with process safety and sustainability. Comparing to official Brazil's government data for oil, the case study showed superiority to the same size platforms, like FPSOs P-75 and MV32, e.g., more than 101.5% more capacity to produce oil in beginning of campaign after first oil, and 10.5% during campaign. The present work indicates that: 1) the production of millions of barrels is being delayed or left aside; 2) not scheduling production harms the environment and diminish process safety; 3) not scheduling production can create stochastic supply chain deliveries instead of organizing it by deterministic offloading days; 4) scheduling is essential to manipulate, revitalize and monitor reservoir's pressure and content under uncertainty; 5) the oil platform can be automatic optimized by a plantwide MPC reducing human activity/dependency; 6) scheduling gives more transparency to stakeholders and contractors by forecasting business data and capability, and can design, develop or enable new businesses.

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Section: State Of the Art And Reviewmentioning

confidence: 99%

Novel Topside and Subsea Production Optimization, Operational Scheduling, and a Generic Plantwide MPC for Process Systems Control and Production Maximization: Oil, Gas, Water and Utilities Decision-Making with Offloading to Supply Chains and Sustainability

Balbino Barbosa Filho,

Farenzena,

Trierweiler

2024

Preprint

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Digital Twin for the Oil and Gas Industry: Overview, Research Trends, Opportunities, and Challenges

et al. 2020

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With the emergence of industry 4.0, the oil and gas (O&G) industry is now considering a range of digital technologies to enhance productivity, efficiency, and safety of their operations while minimizing capital and operating costs, health and environment risks, and variability in the O&G project life cycles. The deployment of emerging technologies allows O&G companies to construct digital twins (DT) of their assets. Considering DT adoption, the O&G industry is still at an early stage with implementations limited to isolated and selective applications instead of industry-wide implementation, limiting the benefits from DT implementation. To gain the full potential of DT and related technological adoption, a comprehensive understanding of DT technology, the current status of O&G-related DT research activities, and the opportunities and challenges associated with the deployment of DT in the O&G industry are of paramount importance. In order to develop this understanding, this paper presents a literature review of DT within the context of the O&G industry. The paper follows a systematic approach to select articles for the literature review. First, a keywords-based publication search was performed on the scientific databases such as Elsevier, IEEE Xplore, OnePetro, Scopus, and Springer. The filtered articles were then analyzed using online text analytic software (Voyant Tools) followed by a manual review of the abstract, introduction and conclusion sections to select the most relevant articles for our study. These articles and the industrial publications cited by them were thoroughly reviewed to present a comprehensive overview of DT technology and to identify current research status, opportunities and challenges of DT deployment in the O&G industry. From this literature review, it was found that asset integrity monitoring, project planning, and life cycle management are the key application areas of digital twin in the O&G industry while cyber security, lack of standardization, and uncertainty in scope and focus are the key challenges of DT deployment in the O&G industry. When considering the geographical distribution for the DT related research in the O&G industry, the United States (US) is the leading country, followed by Norway,

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Building a Low-Manned Production Installation: Considerations for Rotating Equipment, Electrical & Automation Systems, and Digitalization

LaGrange

2021

Day 4 Fri, September 10, 2021

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Nearly all oil and gas operators and engineering companies in the offshore sector today are engaged in programs to advance concepts for low-manned and/or normally unattended production installations (NUIs). When it comes to the design of these facilities, topsides rotating equipment and electrical, instrumentation, control, and telecommunications (EICT) packages represent key areas of interest for decision-makers, owing to the significant impact they can have on required manning levels. Over the past decade, the author's company has worked closely with major Operators in the U.S. and the North Sea to look at how existing technologies can be applied in these areas to safely facilitate de-manning of both brownfields and greenfields. This paper provides insight into these efforts. It also presents projected manpower and cost savings from de-manning, using data derived from both studies and real-world projects.

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FPSO 4.0: Powering Deepwater Production and Optimizing the Lifecycle Performance of Offshore Rotating Equipment Packages

Cited by 3 publications

References 3 publications

Novel Topside and Subsea Production Optimization, Operational Scheduling, and a Generic Plantwide MPC for Process Systems Control and Production Maximization: Oil, Gas, Water and Utilities Decision-Making with Offloading to Supply Chains and Sustainability

Novel Topside and Subsea Production Optimization, Operational Scheduling, and a Generic Plantwide MPC for Process Systems Control and Production Maximization: Oil, Gas, Water and Utilities Decision-Making with Offloading to Supply Chains and Sustainability

Digital Twin for the Oil and Gas Industry: Overview, Research Trends, Opportunities, and Challenges

Building a Low-Manned Production Installation: Considerations for Rotating Equipment, Electrical & Automation Systems, and Digitalization

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