Field Development using Semisubmersible Floating Production System with Steel Catenary Risers in Western Australia Harsh Environment

2014 ◽  
Author(s):  
Alaa M. Mansour ◽  
Shankar Bhat ◽  
Dharma Pasala ◽  
Dhiraj Kumar
Keyword(s):  
Western Australia ◽  
Production System ◽  
Harsh Environment ◽  
Field Development ◽  
Steel Catenary Risers

Steel Lazy Wave Riser Design for Semi-Submersible in Harsh Environment

2014 ◽  
Author(s):  
Jingyun Cheng ◽  
Peimin Cao
Keyword(s):  
Water Depth ◽  
Optimal Solution ◽  
Cost Effective ◽  
Harsh Environment ◽  
Depth Range ◽  
Strength Performance ◽  
Field Development ◽  
Steel Catenary Risers ◽  
Riser Design ◽  
Design Guidance

Deep draft production semi-submersible with steel lazy wave risers (SLWRs) has been studied for the 2,625ft water depth in harsh environment. The design challenges and feasibility of steel catenary risers (SCRs) for semi-submersible at relatively shallow water and harsh environment are discussed. The benefits of using SLWRs to improve riser strength and fatigue performance are presented. Due to the complexity of SLWR geometry, a systematic configuration approach is introduced to achieve the desired riser performance target. A comparison study on fatigue and strength performance of various riser configurations is performed. The assessment provides design guidance for the optimal solution of the integrated hull, mooring and riser system. It concludes that deep draft production semi-submersible with SLWRs can be a feasible and cost effective solution for field development at water depth range from 2,297ft to 3,281ft in harsh environment.

Offshore Gas Field Development Strategy and Flow Assurance Prediction and Optimization in Harsh Environment

2018 ◽  
Author(s):  
Humoud Almohammad ◽  
Abdullah Al-Derbass ◽  
Abdulaziz Alsubaie ◽  
Mohammed Bumajdad ◽  
Abdulaziz Al-Khamis ◽  
...  
Keyword(s):  
Development Strategy ◽  
Harsh Environment ◽  
Flow Assurance ◽  
Gas Field ◽  
Field Development

Aasta Hansteen Subsea Production System for Deep Water and Harsh Environment

2019 ◽  
Author(s):  
Severin Lindseth ◽  
Elling Røsby ◽  
Brynjar Vist ◽  
Knut Axel Aarnes
Keyword(s):  
Deep Water ◽  
Production System ◽  
Harsh Environment ◽  
Subsea Production System

The Pyrenees development: a new oil development for Western Australia

2010 ◽  
Vol 50 (1) ◽  
pp. 241
Author(s):  
Tony Slate ◽  
Ralf Napalowski ◽  
Steve Pastor ◽  
Kevin Black ◽  
Robert Stomp
Keyword(s):  
Western Australia ◽  
Oil Recovery ◽  
Oil And Gas ◽  
Flow Meters ◽  
Field Development ◽  
Oil And Gas Fields ◽  
Sand Control ◽  
Concurrent Development ◽  
Gas Fields ◽  
Offshore Oil

The Pyrenees development comprises the concurrent development of three oil and gas fields: Ravensworth, Crosby and Stickle. The fields are located in production licenses WA-42-L and WA-43-L, offshore Western Australia, in the Exmouth Sub-basin. The development will be one of the largest offshore oil developments in Australia for some time. It is a complex subsea development consisting of a series of manifolds, control umbilicals and flexible flowlines tied back to a disconnectable floating production, storage and offloading (FPSO) vessel. The development involves the construction of 17 subsea wells, including 13 horizontal producers, three vertical water disposal wells and one gas injection well. The project is presently on production with first oil achieved during February 2010. This paper gives an overview of the field development and describes the engineering and technologies that have been selected to enable the economic development of these fields. The Pyrenees fields are low relief, with oil columns of about 40 metres in excellent quality reservoirs of the Barrow Group. Two of the fields have small gas caps and a strong bottom water drive common to all fields is expected to assist recovery. The oil is a moderate viscosity, low gas-to-oil ratio (GOR), 19°API crude. Due to the geometry of the reservoirs, the expected drive mechanism and the nature of the crude, effective oil recovery requires maximum reservoir contact and hence the drilling of long near horizontal wells. Besides the challenging nature of well construction, other technologies adopted to improve recovery efficiency and operability includes subsea multiphase flow meters and sand control with inflow control devices.

The Gjøa Semi: a North Sea project relevant for Western Australia

2011 ◽  
Vol 51 (1) ◽  
pp. 589
Author(s):  
Kristian Aas ◽  
Lars Bjørheim
Keyword(s):  
North Sea ◽  
Western Australia ◽  
Oil And Gas ◽  
Development Project ◽  
Conceptual Level ◽  
Field Development ◽  
The North ◽  
Heavy Lift ◽  
The North Sea ◽  
Field Location

Gjøa was the largest field development project in Norway in 2010. Gjøa was proven in 1989 and are now being developed together with nearby Vega satellites. The combined reserves are estiThe recent Gjøa field development in the North Sea has many features that are relevant for the oil and gas developments north of Western Australia. While the field location is not very similar to the north of Western Australia, the field development solution is very relevant. Several subsea clusters are tied back to a semi-submersible platform with export of gas and condensate via pipelines to shore. Other aspects to the project that are relevant to Western Australia are split location engineering between Norway and India, fabrication of the hull in Korea and subsequent heavy lift transport to the assembly yard, pre-installation of the mooring system, and tow to field with ocean going tug boats. The semi concept, which was used for the Gjøa development, is a mature technology with few technical challenges on a conceptual level. On the other hand the building of an oil and gas platform for A$2 billion has many challenges, both economical and technical, that have to be solved to have a successful project for both the client and the contractor.

On the Subsea Production System Availability with Resident Drones. A Reliability, Availability, Maintenability RAM Analysis

2021 ◽  
Author(s):  
Matteo Mattioli ◽  
Annamaria Di Padova
Keyword(s):  
Production System ◽  
Historical Data ◽  
Economic Value ◽  
Operating Conditions ◽  
System Availability ◽  
Field Development ◽  
Recent Developments ◽  
Subsea Production System ◽  
Reliable Solution

Abstract The challenge in the Oil&Gas industry to remain competitive in a low oil price whilst dealing with minimization of operational risk and uptime asset maximization is leading offshore Companies to evolve thought proactive and predictive maintenance approaches. In the event of unplanned intervention due to anomalies or warning messages at the dispatching center, the decision on the size of the support vessel and its utilization for straordinary maintenance could be time consuming with potential high cost impact, also due to loss of production. Even the new generation of remote condition and monitoring systems, which allow to improve the capability of operators for early warnings and surveillance, provide a reliable solution for emergencies. In this context, resident subsea drones enable on-demand inspection whilst eliminating the need for support vessel and allow operator to manage the risk in continued operations also for dangerous areas restricted to human access. A case study relevant to a new subsea field development have been conducted. Distinctive Reliability, Availability and Maintainability (RAM) analyses have been performed with the aim to get insight on the subsea production system availability considering a resident drone and to demonstrate how the so called "stategic maintainability" can be applied successfully in the decision-making process while reducing the OPEX. The former related to conventional IMR (Inspection, Maintenance & Repair) based on Condition Based and RBI, Risk Based Inspection approach, the latter related to strategic maintenability with resident drones. The application of such analysis required a multi-disciplinary approach together with the possibility of processing historical data in operating conditions. Historical data sources (e.g. OREDA dataset) were collected to obtain failure rates and active repair times typical of subsea equipment. Direct experience gained in over forty years of inspection and maintenance activities together with recent developments on subsea resident robotics allow the understanding of real internvention timing. Results show that resident subsea drones applied for early inspection and light intervention are confirmed timely and costless solution respect to conventional IMR services. They represent the first aid for environmental surveillance and subsea inspection in case of emergency and provide a relevant saving of subsea production un-availability. The economic value emerged from the presented case study represents a step change for OPEX optimization and motivates Best-in-Class Operators to get an insight case-by-case for both green and aging fields.

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