SBM Offshore N.V. is a Dutch-based global group of companies selling systems and services to the offshore oil and gas industry. Its constituent companies started their offshore activities in the early 1950s and SBM subsequently became a pioneer in single point mooring systems. The firm leases and operates Floating Production Storage and Offloading vessels, and is involved in the design and engineering, the construction, the installation, the operation and the life extension of floating production solutions for the offshore Oils and Gas industry. It is a main board listed company on the Euronext Amsterdam stock exchange and has been a member of the AEX index since 2003. Wikipedia.
De Souza R.,SBM offshore
Proceedings of the Annual Offshore Technology Conference | Year: 2013
Since Law No. 9.478/97 was enacted, the ANP (National Agency of Petroleum, Natural Gas and Biofuels) has been looking forward to enhance local content for the areas offered in its rounds. After several tender processes, local content requirements had become decisive for the concession contract winners. Consequently, all the concessionaire supply chain had to evidence the local content of its products and services in accordance to the existing rules. As result, the local content that could be achieved by each E&P (Exploration & Production) supplier becomes a great competitive differential in Brazilian oil market. In this context, foreign companies interested in taking advantage of the growing opportunities in the E&P segment in Brazil, started to look for alternatives and structures capable of adding local content to their products and services. The concession contracts for offshore blocks have the highest local content commitments during the development phase. This is because there are huge investments in goods and services acquirement, particularly in the acquisition of a production unit like FPSOs (Floating production, storage and offloading) which are particularly efficient due to its mobility in different areas. The construction and installation for a FPSO, for instance, generates significant demand for such goods and services that may impact the entire local supply chain. The lack of availability these acquisitions in the Brazilian market may adversely affect the attractiveness of projects. Thus, we highlight the importance of a more appropriate method that considers both the profit margin as local content committed by the concessionaires with ANP. Considering the relevance of the scenario presented above, this paper aims to suggest a method that supports the decision-making that complies with the required local content index and the operator preference. The original view on Brazilian regulatory environment, contributes to improve local content strategy in petroleum industry. The work is developed briefly presenting: method of decision support; oil industry in Brazil; regulatory market and local content policies. Copyright 2013, Offshore Technology Conference.
Hwang J.-H.,SBM offshore |
Roh M.-I.,University of Ulsan |
Lee K.-Y.,Seoul National University
Computers and Chemical Engineering | Year: 2013
With the increased demand for natural gas, there has been an increase in the research on and development of liquefied-natural-gas floating, production, storage, and offloading unit (LNG FPSO) technologies for LNG service in place of onshore LNG plants. The dual mixed refrigerant (DMR) cycle, which precools natural gas with the mixed refrigerants of ethane, propane, butane, and methane and then liquefies the natural gas with another set of mixed refrigerants (nitrogen, methane, ethane, and propane), is well known for having the highest efficiency among the liquefaction cycles, and is being examined for possible application to LNG FPSO. In this study, the optimal operating conditions for the DMR cycle are determined by considering the power efficiency. For this, a mathematical model of the DMR cycle was formulated in this study by referring to the results of a past study that formulated a mathematical model of the single mixed refrigerant (SMR) cycle. Finally, the optimal operating conditions from the formulated mathematical model were obtained using a hybrid optimization method that consists of the genetic algorithm (GA) and sequential quadratic programming (SQP). As a result, the required power at the determined optimal operating conditions was decreased by 34.5% compared with the patent (Roberts & Agrawal, 2001), and by 1.2% compared with the corresponding value from the past relevant study (Venkatarathnam, 2008). © 2012 Elsevier Ltd.
Rijken O.,SBM offshore
Proceedings of the International Conference on Offshore Mechanics and Arctic Engineering - OMAE | Year: 2013
A common procedure of installing a Tension Leg Platform is to float it over the tendons and lower it over the tendons. A key phase of this procedure is lock-off, i.e. the instant when the tendons become firmly attached to the TLP hull. The lock-off position of the tendons on the hull should be within specified tolerances. Lock-off on the tendons higher than targeted results in a reduced draft which implies reduced displacement and therefore typically reduced payload capacity or reduced payload reserve. Lock-off on the tendons lower than targeted results in increase in draft and brings the deck closer to mean water which adversely affects the airgap requirements. Hence lock-off at the correct draft is a key aspect of a successful installation procedure. The general geometric properties of several TLPs are such that there is a significantly more heave motion under swell conditions than under sea states with much smaller peak periods (for the same significant wave height). These larger motions under swell conditions can make it harder to achieve the desired lock-off elevation. Such swell conditions are known to occur of the West Coast of Africa. Waiting for the swell to subside may not be an attractive alternative for TLP installation as these swells may be present for extended periods of time. Two engineering solutions are provided which reduce the heave motion of a free floating TLP. Both of these solutions are temporary changes to the TLP itself and should be implemented as a part of the TLP design spiral. One of the solutions implies an increase of TLP mass; the second solution reduces the vertical stiffness of the free floating TLP. The heave natural period is significantly increased in both methods, and heave motions are reduced. Both methods increase the heave response amplitude operator (RAO) for periods below 8 to 12 seconds and reduce the heave RAO magnitudes above 12 seconds. Implementing one of these methods in the installation procedure may be most applicable to situations where the installation window may contain prolonged periods of persistent swell. Copyright © 2013 by ASME.
Newport A.,SBM offshore
Marine Technology | Year: 2014
The article discusses how reliability, safety, cost, and environmental factors affect how a floating production unit (FPU) is connected to the seabded. FPUs need to remain on station, within certain limits, to protect the integrity of the riser system that connects the subsea wells or pipelines to the FPU. There are various types of riser systems and configurations that can be used, but all have limitations in the excrusions they can accept to avoid rupture or long-term fatigue. The mooring legs of FPUs in shallow water, whether turret moored or spread moored, are generally composed of chain. The weight of the chain is used to provide a restoring force as the unit drifts off station under the action of wind, waves, and current. The mooring legs are arranged in groups, or bundles, and hang from the FPU in a catenary arrangement.
Rijken O.,SBM offshore
Proceedings of the Annual Offshore Technology Conference | Year: 2013
Dry tree solutions, i.e. the well heads located at deck level, can be an attractive solution to sustain or improve production from one or more offshore oil or gas fields. Existing dry tree solutions have been implemented on Tension Leg Platforms (TLP's) and Spar Platforms. The TLP reaches an economical and thus feasible limit at a water depth exceeding 6000 ft to 7000 ft; Spar technology has been successfully applied at water depths exceeding 6000 ft. A key element for dry tree technology is the riser tensioner, for both production risers and drilling riser(s). TLP's use relatively short stroke tensioners while spar platforms use relatively long stroke tensioners. Spar riser technology is field proven. Production semisubmersibles have been successfully installed in water depths up to 9000 ft and have proven to be robust systems. Quayside integration and quayside commissioning are two of the economic advantages of the semisubmersible. A semisubmersible requires typically significantly more tensioner stroke than a spar under the same environmental conditions. However, stroke requirements for semisubmersibles in the more benign regions of the world, such as of the African or Brazilian coasts, are on the order of typical spar tensioners requirements. This indicates that a dry tree semisubmersible is technically possible for those more benign locations. There are several distinct variants of the dry tree semisubmersible. They include a well head semisubmersible, i.e. a work-over rig with minimal facilities; a drilling semisubmersible, i.e. full drilling capability; and a drilling & production semisubmersible, i.e. the hydrocarbons are processed on the facility before offloading. The sizing of a dry tree semisubmersible requires a careful balance between the various requirements; some of those requirements are documented in a Basis of Design document, while other requirements are not documented outright but arise from the planned construction yard, e.g. quayside draft and crane capacity, the planned transportation methodology, or the country's jurisdiction, e.g. local content. The focus of this paper is to present a drilling and production dry tree semisubmersible and to identify some of the major variations in size which are the result of variants on the design requirements and/or construction requirements. Copyright 2013, Offshore Technology Conference.