A Model-Based System Metaheuristic Engineering MBSME Approach in the Conceptual Selection of Offshore Production Units

2021 ◽  
Author(s):  
Leandro Pereira Basilio ◽  
Priscilla Badega Machado ◽  
Débora Calaza de Sousa ◽  
Rafael Vinicius de Castro ◽  
Diego Russo Juliano ◽  
...  
Keyword(s):  
Systems Engineering ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Gas Industry ◽  
Field Development ◽  
Model Based ◽  
Offshore Production ◽  
Tradespace Exploration ◽  
Offshore Field ◽  
Selection Of

Abstract The objective of this paper is to present and discuss the philosophy behind the integration of "Model-Based Systems Engineering" (MBSE) with metaheuristic algorithms, referred to as "Model-Based Systems Metaheuristic Engineering" (MBSME), which has demonstrated high potential of techno-economic optimization of large capital projects in oil and gas industry, notably in the automatic and integrated conceptual design and selection of offshore systems architectures. Virtual modeling has always been an important part of systems engineering to support functional, performance and other engineering analysis. The so-called MBSME allows the simulation of several specific System-of-Systems physically addressed in offshore field development, bringing all the benefits of the traditional MBSE approach, and set a stochastic characteristic in the analysis, allowing the project team to focus on a Model-Centric approach, as well as to quickly understand the influence of several combined project strategies and application of different technologies, communicated through a Tradespace exploration map. Due to the characteristics associated with and the countless number of variables of the multidimensional problem addressed in an offshore field development, the integration of "Meta-Heuristic" algorithms with "Model-Based Systems Engineering" has demonstrated a remarkable efficiency and powerful applicability in the search for optimized design solutions in oil and gas industry, especially considering the processes of generation of conceptual alternatives of offshore production systems. This method leads to a reduction of more than 2/3 of the average time currently observed, with an increase in the number of conceptual alternatives evaluated in the order of tens to an order of thousands of options, in an automatic and integrated approach. Although the digital MBSME already developed addresses the combination of all technical disciplines associated with a complete offshore field development, the current work emphasizes the latest R&D achievements, addressing the automatic design and specification of Topside Facilities architecture, combined with the automatic selection of fitting for purpose Production Unit, based on internal requirements, such as the required capacity to support total weight and footprint imposed by the topside facilities’ modules, as well as external requirements, like water depth, surface metocean, type of well completion and oil storage requirements. An example of the MBSME application is presented, demonstrating a three-dimensional Tradespace exploration, relating Net Present Value (NPV), Capital Expenditure (CAPEX) and Breakeven Oil Price, through the application of a computational package in a hypothetical project, reflecting the design conditions of an offshore development in the Brazilian Pre-Salt region. The paper communicates an efficient method to increase the scope and accuracy of conceptual analyses, leading to the identification of the most favorable techno-economic conditions to the particularities of each project, supporting significant increases of return on investments.

Challenges of Developing Marginal Fields in the Current Climate of Oil and Gas Industry

2021 ◽  
Author(s):  
Amina Danmadami ◽  
Ibiye Iyalla ◽  
Gbenga Oluyemi ◽  
Jesse Andrawus
Keyword(s):  
Oil And Gas ◽  
Dynamic Environment ◽  
Poor Performance ◽  
Oil And Gas Industry ◽  
Economic Benefits ◽  
Gas Industry ◽  
Field Development ◽  
Quality Technology ◽  
Indigenous Participation ◽  
Marginal Field

Abstract Marginal field development has gained relevance in oil producing countries because of the huge potential economic benefits it offers. The Federal Government of Nigeria commenced a Marginal Fields program in 2001 as part of her policy to improve the nation’s strategic oil and gas reserves and promote indigenous participation in the upstream sector. Twenty years after the award of marginal fields to indigenous companies to develop, 50% have developed and in production, 13% have made some progress with their acquisition while 37% remain undeveloped. The poor performance of the marginal field operators is due to certain challenges which have impeded their progress. A review of challenges of developing marginal fields in the current industry climate was conducted on marginal fields in Nigeria to identify keys issues. These were identified as: funding, technical, and public policy. Considering the complex, competitive and dynamic environment in which these oil and gas companies operate, with competition from renewables, pressure to reduce carbon footprint, low oil price and investors expectation of a good return, companies must maintain tight financial plan, minimize emissions from their operations and focus on efficiency through innovation. The study identifies the need for a decision-making approach that takes into consideration multi criteria such as cost, regulation, quality, technology, security, stakeholders, safety and environment, as important criteria based on which to evaluate the selection of appropriate development option for marginal fields.

Quantifying Economic Uncertainties and Risks in the Oil and Gas Industry

2021 ◽  
pp. 154-184
Author(s):  
Sorin Alexandru Gheorghiu ◽  
Cătălin Popescu
Keyword(s):  
Business Performance ◽  
Oil And Gas ◽  
Water Injection ◽  
Oil And Gas Industry ◽  
Oil Field ◽  
Gas Industry ◽  
Field Development ◽  
Drilling Rig ◽  
Oil Field Development ◽  
Oil Gas

The present economic model is intended to provide an example of how to take into consideration risks and uncertainties in the case of a field that is developed with water injection. The risks and uncertainties are related, on one hand to field operations (drilling time, delays due to drilling problems, rig failures and materials supply, electric submersible pump [ESP] installations failures with the consequences of losing the well), and on the other hand, the second set of uncertainties are related to costs (operational expenditures-OPEX and capital expenditures-CAPEX, daily drilling rig costs), prices (oil, gas, separation, and water injection preparation), production profiles, and discount factor. All the calculations are probabilistic. The authors are intending to provide a comprehensive solution for assessing the business performance of an oil field development.

Financing Requirements for the Oil and Gas Industry - North America

1988 ◽  
Vol 6 (4-5) ◽  
pp. 317-322
Author(s):  
A.F. Grove
Keyword(s):  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Gas Field ◽  
Gas Industry ◽  
Field Development ◽  
Energy Company ◽  
Corporate Credit ◽  
Oil And Gas Field ◽  
Good Energy ◽  
Business Acumen

The characteristics of good energy company borrowers are strong management, integrity, diversification, flexibility, a sound financial basis and business acumen. Acceptable reasons for borrowing include requirements for working capital, plant expansion, modernisation, oil and gas field development and the manufacturing of oil tools and related products. Security for loans is based on the company's reserves, the duration of the debt and priority over other indebtedness. Most loans are evaluated on the grounds of general corporate credit, that is, the overall credit standing of the borrower.

scholarly journals Evaluation of Oil and Gas Economy using Economics Profit Indicators and Prototype Macro VBA Excel

2021 ◽  
Vol 1 (1) ◽  
pp. 549-558
Author(s):  
Juwairiah Juwairiah ◽  
Didik Indarwanta ◽  
Frans Richard Kodong
Keyword(s):  
Economic Analysis ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Development Project ◽  
Economic Indicators ◽  
Gas Field ◽  
Gas Industry ◽  
Field Development ◽  
Oil And Gas Field ◽  
Oil And Gas Sector

The oil and gas sector is an important factor in sustainable development, so it is considered necessary to make serious changes in conducting economic analysis on the oil and gas business. Oil and gas industry activities consist of upstream activities, and downstream activities. Activities in these upstream and downstream operations have high risk, high costs and high technology, so the company continuously tries to reduce the importance of the adverse impact of these risks on the work environment and people. Thus, evaluating the factors that affect sustainable production in this sector becomes a necessity. In this research will be evaluated the economy of the oil and gas field using methods of economic indicators, among others; NPV, POT, ROR, where these factors are estimated in order to be able to estimate the prospects of the oil and gas field so that the decision that the field development project can be implemented or cannot be taken immediately. Implementation of oil and gas field economic evaluation in this study using Macro VBA Excel. From several methods of economic analysis obtained that the results of this study show high precision compared to other methods, in addition to the way of evaluation using the above economic indicators is very popular.

scholarly journals Digital oil and gas complex of Russia

Georesursy ◽  
2020 ◽  
pp. 32-35 ◽  
Author(s):  
Anatoliy N. Dmitrievskiy ◽  
Nikolay A. Eremin ◽  
Dina S. Filippova ◽  
Elizaveta A. Safarova
Keyword(s):  
Fiber Optics ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Gas Industry ◽  
Field Development ◽  
Intelligent Control Systems ◽  
Geological Processes ◽  
Technological Modernization ◽  
Gas Market ◽  
Academy Of Sciences

Digital and technological modernization of the oil and gas industry through the use of innovative technologies and platform solutions, intelligent control systems, domestic “end-to-end” digital technologies will help strengthen Russia’s position in the global oil and gas market. One of the megascience projects being developed at the Institute of Oil and Gas Research Institute of the Russian Academy of Sciences is the creation of a Geosphere Observatory. The Geosphere Observatory is focused on studying the influence of fundamental geological processes (crustal waveguides, fracture centers, etc.) in the mantle and crust of the Earth on the formation of hydrocarbon accumulations and management of field development in real time based on the introduction of advanced technologies in the field of ultra-deep drilling, fiber optics and laser physics, processing large volumes of geo-information (BigGeoData) and the theory of reconfigurable active-passive sensor networks (AntennaGrid).

scholarly journals On Disaster Risk Reduction in Norwegian Oil and Gas Industry Through Life-Cycle Perspective

2019 ◽  
Author(s):  
Michaela Ibrion ◽  
Nicola Paltrinieri ◽  
Amir R. Nejad
Keyword(s):  
Life Cycle ◽  
Risk Reduction ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Learning And Development ◽  
Gas Industry ◽  
Life Cycle Perspective ◽  
Offshore Field ◽  
Perspective Analysis ◽  
Reduction Of Uncertainty

Abstract This paper presents the risk reduction in Norwegian oil & gas industry over the time (1975–2016) through a life cycle perspective analysis with the aim to identify the critical stage(s) both in terms of accident occurrence and cause of the accident. Fifteen accidents, major accidents and disasters for example Ecofisk 2/4 Alpha 1975, Alexander L. Kielland 1980, Songa Endurance 2016 were studied. Cases from outside of the Norwegian offshore field — the Piper Alpha 1988, the Bourbon Dolphin 2007, and the Deep Water Horizon 2010 — were also considered as comparison. For each accident and through the life cycle analysis, the occurrence stage of the accident and its main technical causes were identified and compared. It was found that a high risk is concentrated in the Operation (In-Service) stage and associated Marine Operations. Furthermore, it was observed that a high number of accidents in oil and gas industry are associated with mobile structures. All the investigated accidents have acted as powerful reminders to the oil and gas industry that a continuous improvement of risk management and reduction of uncertainty are of paramount importance in order to ensure safe operations and risk reduction for accidents, major accidents and disasters. However, a reactive learning from major accidents and disasters needs to be supported by a proactive learning and development of a dynamic risk culture in the oil and gas industry.

Direct electric heating: an environmentally friendly flow-assurance tool

2013 ◽  
Vol 53 (2) ◽  
pp. 448
Author(s):  
Ingebjørg Lien
Keyword(s):  
Oil And Gas ◽  
Environmentally Friendly ◽  
Electric Heating ◽  
Oil And Gas Industry ◽  
Electrical Circuit ◽  
Flow Assurance ◽  
Critical Temperatures ◽  
Gas Industry ◽  
Field Development ◽  
Hydrate Plug

In subsea flowlines, water in the line can form an ice-like structure called a hydrate plug. Wax appearance in flowlines also is a common flow assurance issue. Hydrate and wax appearance can reduce or stop production for weeks. Preventing hydrate and wax in pipelines is a major concern for the oil and gas industry. Direct electric heating (DEH) is a modern and environmentally friendly flow-assurance tool that can reduce capital expenditures (CAPEX) and operating expenditures (OPEX) in field development, reduce the probability of pollution, and reduce handling of toxic disposals as a result of traditional chemical flow assurance methods. DEH is based on using the pipeline as part of the electrical circuit, generating losses in the steel pipe to keep the pipeline and its content above the critical temperatures. Use of DEHs also increases the efficiency at the process plant after planned or unplanned production stops. For marginal fields and fields with heavy or waxy oil, DEH is a flow-assurance method that can enable these fields to be developed profitably. DEH is now a mature technology used for 13–14 years on the Norwegian continental shelf and technology implemented and used in West Africa recently. How successful this technology has been can be summarised by the Tyrihans field where Statoil quoted that they—on this project alone—saved about $USD175 million by implementing DEH. Wärtsilä has been part of the DEH development in Norway since the 90s, and undertakes design and supply of the complete topside power package in addition to electric and optical protection specially developed for DEH systems.

Matching of Gas Turbines and Centrifugal Compressors: Oil and Gas Industry Practice

2012 ◽  
Author(s):  
Matt Taher ◽  
Cyrus Meher-Homji
Keyword(s):  
Gas Turbine ◽  
Centrifugal Compressor ◽  
Gas Turbines ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Site Conditions ◽  
Centrifugal Compressors ◽  
Gas Industry ◽  
Compressor Design ◽  
Selection Of

Gas turbine driven centrifugal compressors are widely used in the oil and gas industry. In evaluating the optimum selection of gas turbine drivers for centrifugal compressors, one of the main objectives should be to verify proper integration and matching of the centrifugal compressor to its gas turbine driver. Gas turbines are of standard designs, while centrifugal compressors are specifically designed to meet customer requirements. The purchaser should clearly specify process requirements and define possible operating scenarios for the entire life of the gas turbine driven centrifugal compressor train. Process requirements defined by the purchaser, will be used by the compressor designer to shape the aero-thermodynamic behavior of the compressor and characterize compressor performance. When designing a centrifugal compressor to be driven by a specific gas turbine, other design requirements are automatically introduced to centrifugal compressor design. Off-design performance, optimum power turbine speeds at site conditions as well as optimum power margin required for a future-oriented design must all be considered. Design and off-design performance of the selected gas turbine at site conditions influences the final selection of a properly matched centrifugal compressor design. In order to evaluate different designs and select the most technically viable solution, the purchaser should have a clear understanding of the factors influencing a proper match for a centrifugal compressor and its gas turbine driver. This paper discusses criteria for evaluating the most efficient combination of a centrifugal compressor and its gas turbine driver as an integral package from a purchaser’s viewpoint. It also addresses API standard requirements on gas turbine driven centrifugal compressors.

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