Rationale of Riser System Selection for an FPSO Application

2007 ◽  
Author(s):  
Liping Sun ◽  
Xiongliang Yao ◽  
Zhenghong Hu
Keyword(s):  
Oil And Gas ◽  
Reservoir Properties ◽  
Technical Feasibility ◽  
Field Development ◽  
Deepwater Riser ◽  
To Come ◽  
Offshore Oil And Gas ◽  
Motion Characteristics ◽  
Deepwater Risers ◽  
System Selection

Floating Production, Storage and Offloading (FPSO) system has been used widely in the offshore oil and gas industries worldwide. In recent years, FPSO concept has been deployed in deep and ultra-deepwater field development including West of Africa, Offshore Brazil, and Offshore China. Meanwhile, more and more deepwater risers have been deployed from concept to offshore installation. Compared to other type deepwater floaters (e.g. Spar, TLP, Semisubmersible), the severe motion characteristics of an FPSO makes the riser concept selection and design much more challenges. Other constraints imposed by field reservoir properties (e.g. high temperature\high pressure), disconnection requirements for early production FPSO system, and significant increase in water depth even exclude some riser concepts. This paper presents detailed evaluation of potential deepwater riser concepts applicable for an FPSO. Among the deepwater concepts, steel catenary risers (SCR), flexible risers, hybrid risers have been successfully deployed to FPSO application. In addition, there are also other viable riser concepts for FPSO application including lazy wave SCR, Tension Leg Riser (TLR), Hybrid ‘S’ Riser System (HySR), Hybrid Catenary Riser (HCR), and more to come. The evaluation of deepwater riser concepts for FPSO application is conducted in terms of technical feasibility, design constraints, track records, fabrication, offshore construction, and cost with focus on the existing and field proven riser concepts. Technical challenges and technology gaps are highlighted. The technical feasibility of some of the riser concepts for certain FPSO application has been demonstrated through analysis and calculation. Novel ideas have been generated for particular requirements. Particular attention is paid to the discussion with the application to offshore China. This paper shows the steel riser and hybrid riser are the most viable ones for deep and ultra-deepwater FPSO. Flexible riser and hybrid riser are the preferred solution for FPSO in China.

SCR Fatigue Feasibility Prediction for Deepwater FPSO Applications

2012 ◽  
Author(s):  
Sherry Xiang ◽  
Peimin Cao
Keyword(s):  
Oil And Gas ◽  
Early Stage ◽  
Design Flow ◽  
Response Analysis ◽  
Field Development ◽  
Steel Catenary Risers ◽  
Fluid Transfer ◽  
Offshore Oil And Gas ◽  
System Selection ◽  
Prediction Approach

Many of the recent offshore oil and gas discoveries in the world have occurred in deep waters, at locations far away from the existing subsea infrastructure. Floating Production Storage and Offloading systems (FPSOs) are the preferred field development solutions for those locations with mild and moderate environments. The simplest fluid transfer system between the seabed and the FPSO is a simple catenary configuration, with Steel Catenary Risers (SCRs) as the preferred solution for deep water, high pressure and high temperature applications. This paper introduces an effective engineering SCR fatigue screening methodology for FPSO applications. The focus of this study is to better understand SCR fatigue performance at Touch Down Point (TDP) and develop a simple but reasonable correlation between FPSO porch motion and the riser dynamic stress response at TDP. This methodology enables one to perform the porch motion statistics analysis and the riser dynamic response analysis independently. By using the wave screening approach, SCR fatigue feasible map can be effectively developed. The paper presents an example performing the fatigue screening evaluation. SCR feasibility design flow chart for FPSO application is also addressed. Particular for FPSO application in a new development, the fatigue feasibility prediction approach along with the strength feasibility check can help the project make the informative decision on the overall FPSO and riser system selection at the early stage of the development.

Is Australia Prepared for the Decommissioning Challenge? A Regulator's Perspective

2021 ◽  
Author(s):  
David Christensen ◽  
Andrew Re
Keyword(s):  
Environmental Management ◽  
Oil And Gas ◽  
Good Practice ◽  
Petroleum Industry ◽  
Health And Safety ◽  
Regulatory Reform ◽  
Field Development ◽  
Independent Expert ◽  
Offshore Oil And Gas ◽  
Offshore Petroleum

Abstract The National Offshore Petroleum Safety and Environmental Management Authority (NOPSEMA) is Australia's independent expert regulator for health and safety, structural (well) integrity and environmental management for all offshore oil and gas operations and greenhouse gas storage activities in Australian waters, and in coastal waters where regulatory powers and functions have been conferred. The Australian offshore petroleum industry has been in operation since the early 1960s and currently has approximately 57 platforms, 11 floating facilities, 3,500km of pipelines and 1000 wells in operation. Many offshore facilities are now approaching the end of their operational lives and it is estimated that over the next 50 years decommissioning of this infrastructure will cost more than US$40.5 billion. Decommissioning is a normal and inevitable stage in the lifetime of an offshore petroleum project that should be planned from the outset and matured throughout the life of operations. While only a few facilities have been decommissioned in Australian waters, most of Australia's offshore infrastructure is now more than 20 years old and entering a phase where they require extra attention and close maintenance prior to decommissioning. When the NOGA group of companies entered liquidation in 2020 and the Australian Government took control of decommissioning the Laminaria and Corallina field development it became evident that there were some fundamental gaps in relation to decommissioning in the Australian offshore petroleum industry. There are two key focus areas that require attention. Firstly, regulatory reform including policy change and modification to regulatory practice. Secondly, the development of visible and robust decommissioning plans by Industry titleholders. The purpose of this paper is to highlight the importance and benefit of adopting good practice when planning for decommissioning throughout the life cycle of a petroleum project. Whilst not insurmountable, the closing of these gaps will ensure that Australia is well placed to deal with the decommissioning challenge facing the industry in the next 50 years.

scholarly journals The features of the geological structure of the Verkhnechonsky oil and gas condensate field and their influence on the field development and operation system

2020 ◽  
Vol 43 (3) ◽  
pp. 350-363
Author(s):  
L. A. Rapatskaya
Keyword(s):  
Oil And Gas ◽  
Horizontal Wells ◽  
Geological Structure ◽  
Field Structure ◽  
Gas Condensate ◽  
Reservoir Properties ◽  
Reservoir Water ◽  
Horizontal Drilling ◽  
Development System ◽  
Field Development

The study aims to analyze the relationship between the redetermination of the complexity of the geological structure of the Verkhnechonsky oil and gas condensate field and the schedule adjustment of the field development plans. The paper uses the data on the exploration and production wells obtained from the pilot operation of JSC Verkhnechonskneftegaz, the geophysical work results, and the research materials publicly available in the press. The geological structure of the Verhnechonskoye oil and gas condensate field is unique in its complexity. This is due to the following factors: a combination of tectonic disturbances accompanied by the intrusion of traps; high mineralization of the reservoir water; sharp variability of the filtration and reservoir properties of the producing horizons by area and section due to the unevenness of the lithological composition of the reservoirs, their salinization and complete pinch-out. The development system of any field should take into account the peculiarities of the field’s tectonic and lithological-facies structure, and meet specific technical and economic requirements for drilling and operating wells. The complexity of the field structure requires a thorough selection of a development system that inevitably changes as the features of the field structure are studied, e.g. vertical drilling suggested at the initial stage of the filed development was shortly after replaced with inclined-horizontal drilling with the calculation of two options. Within the pilot operation project of the Verkhnechonsky field, JSC Verkhnechonskneftegaz has developed two variants of uniform grids of directional and horizontal wells with pattern flooding for the most explored deposits of the Verkhnechonsky horizon of blocks I and II. Because of the intensive processes of the reservoirs’ secondary salinization, the flooding method required a study of the reservoir water composition. However, the proposed drilling plan using a downhole engine and gamma-ray logging could not ensure the wellbores ducting through the most productive sections of the horizon, therefore, the flow rates of some directional and horizontal wells were not high enough. To increase the drilling efficiency, the specialists of the Drilling Department (JSC Verhnechonskneftegaz), together with the Department of Geology and Field Development (Schlumberger Ltd.), proposed a new methodology that increases the drilling efficiency by using a rotary-controlled system, logging-while-drilling, and geosteering. Thus, the development system of the Verkhnechonsky oils and gas condensate field was changing in the process of specifying the field’s geological structure, anisotropy reservoir properties, and the thickness of the producing horizons in size and cut, their salinization and pinch-out, and the composition of the reservoir waters.

scholarly journals Modern Political and Economic Aspects of the Oil and Gas Complex in the Southeast Asia Region

2014 ◽  
pp. 54-59
Author(s):  
V. I. Salygin ◽  
S. V. Berezinskiy
Keyword(s):  
Southeast Asia ◽  
Oil And Gas ◽  
American Business ◽  
Gas Field ◽  
Field Development ◽  
Oil And Gas Fields ◽  
Oil And Gas Field ◽  
Offshore Oil And Gas ◽  
Gas Fields ◽  
Offshore Oil

AbstracUThe article reviews the problems caused by the conflict of interests between certain Southeast Asian countries and other states, China foremost, which aroused from oil and gas field development on disputable offshore sections. At the same time the positions of the region's leading transnational corporations in the field of oil and gas policy and their relationships with the countries-ASEAN (Association of South East Asian Nations) members are outlined. Separately are represented the foreign policy stands of Indonesia, Vietnam, Brunei, Philippines and Malaysia on territorial disputes over offshore oil and gas fields. These processes are pushing both European and American business to abandon the conventional schemes and accept the new conditions of their activity in Southeast Asia.

Optimal Design and Scheduling of Offshore Oil and Gas Field Development with Environmental Impact Consideration

2021 ◽  
Author(s):  
Novita Dwi Putri Nugraheni ◽  
Jie Li
Keyword(s):  
Environmental Impact ◽  
Oil And Gas ◽  
Pareto Optimal ◽  
Gas Field ◽  
Pareto Optimal Front ◽  
Field Development ◽  
Minlp Model ◽  
Oil And Gas Field ◽  
Offshore Oil And Gas ◽  
Offshore Oil

Abstract The objective of the paper is to develop a mixed integer nonlinear programming (MINLP) model for optimum design and scheduling of offshore oil and gas field development in respect to simultaneous consideration of economic and environmental impact. The model is utilized as a tool for decision making management in conceptual stage. Nonlinear reservoir behavior and floating demand constraint are incorporated to improve accuracy of the solution. This paper utilizes mathematical programming techniques to address the design and scheduling problem of offshore oil and gas field development. Field development problem is first formulated into a multi-objective MINLP model incorporating many realistic features such as nonlinear reservoir behavior and floating demands. The objectives are to maximize net present value (NPV) and minimize total environmental impact (TEI) simultaneously. Environmental impact is assessed using the ReCiPe2016 method. Augmented ε-constraint method (AUGMECON) is then employed to solve the proposed multi-objective MINLP model to generate the Pareto-optimal front that is able to assist decision maker selecting the most preferred solution. The performance of the proposed modelling framework is investigated on a set of problem which consists of 2 reservoirs, 2 FPSOs, 2 customers and 5-years planning horizon. First model with single objective function to maximize NPV can be solved effectively within short computational time. The solution gives optimum decision of design, investment, production schedule, and transportation regardless the environmental impact. Then, simultaneous optimization of multi-objective MINLP with different value of ε-constraint generates multiple development schemes and objective function values. The results indicate trade-off between maximizing NPV and minimizing TEI. It is possible to obtain maximum NPV of USD 2.4 trillion at the expense of TEI which is 307.518 or to generate minimum TEI of 16.65 at the expense of NPV which is USD 74.368 billion. All possible solutions within extreme values range are presented in form of a Pareto-optimal front where TEI and NPV are plotted in x and y-axis respectively. It will assist the company to select the most preferred solution based on NPV. Consequently, the selected option brings corresponding value of TEI. Additionally, the Pareto optimal front also allows decision maker to have more flexibility to compromise between economic and environmental issues. This is the first study to consider environmental impact in the offshore oil and gas field development. Many realistic operational features such as nonlinear reservoir behavior and floating demands are also incorporated. In addition to that, the proposed framework yields a powerful tool to assist decision maker selecting the most preferred solution that satisfies their criteria in both economic and environmental aspects.

NOVEL PRODUCTION CONCEPTS FOR DEEP WATER AND ASSOCIATED HYDRODYNAMIC PROBLEMS

1998 ◽  
Vol 38 (1) ◽  
pp. 855
Author(s):  
K.P. Thiagarajan
Keyword(s):  
Deep Water ◽  
Oil And Gas ◽  
Production Systems ◽  
Gas Production ◽  
Oil And Gas Production ◽  
Cylindrical Structures ◽  
Campos Basin ◽  
Offshore Oil And Gas ◽  
Motion Characteristics ◽  
Offshore Oil

Offshore oil and gas production is now reaching to great depths, in excess of 1000 m, in the Gulf of Mexico and the Campos Basin, offshore Brazil. It will not be long before Australian companies look towards probable reserves in deeper waters that still remain within the Australian exclusive economic zone. Production concepts for deep and ultra deep water thus need to be studied and researched, and a constant watch should be maintained on developments around the world in this area.This paper presents two popular, and constantly evolving, concepts for deep water, namely: tension leg platforms (TLP) and spars. Tension leg platforms have been in existence for about 14 years, and are actively sought for deep water by worldwide operating companies. They are vertically moored by means of taut tethers which present interesting motion characteristics and unique hydrodynamic problems. Spar platforms are currently being installed for production purposes. These are large deep draft cylindrical structures moored by catenary or taut spread mooring systems. Physical details, advantages and limitations of both systems are discussed.While many aspects of these production systems are now understood, there are still several unknowns. Deeper waters translate to newer problems. Potential problems of the future are discussed in this paper, and research needs are highlighted.

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