ISO Offshore Structures Standards

2011 ◽  
Author(s):  
Philip Smedley ◽  
Pat O’Connor ◽  
Richard Snell
Keyword(s):  
Oil And Gas ◽  
Steel Structures ◽  
Oil And Gas Industry ◽  
Offshore Structures ◽  
National Standards ◽  
Gas Industry ◽  
Technical Content ◽  
Technical Advances ◽  
Integrity Management ◽  
Specific Assessment

The ISO 19900 series of Standards address the design, construction, transportation, installation, integrity management and assessment of offshore structures. Offshore structural types covered by ISO include: bottom-founded ‘fixed’ steel structures; fixed concrete structures; floating structures such as monohull FPSOs, semi-submersibles and spar platforms; arctic structures; and site-specific assessment of jack-up platforms. All the fundamental ISO Offshore Structural Standards have now been published representing a major achievement for the Oil and Gas Industry and representative National Standards Organizations. A summary of the background to achieving this milestone is presented in this paper. In parallel, other Codes and Standards bodies such as API, CEN, CSA, Norsok and the Classification Societies are looking to harmonize some, or all, of their Offshore Structures Standards in-line with ISO, wherever this is desirable and practical. API, in particular, have been pro-active in reviewing and revising their Offshore Recommended Practices (RPs) to maximize consistency with ISO, including revising the scope and content of a number of existing API RPs, adopting ISO language, and embracing technical content. Given API’s long heritage of Offshore Standards it is not surprising that this remains very much a mutual effort between ISO and API with much in ISO Standards building on existing API design practice. Now published, those involved in developing and maintaining the ISO 19900 series of Standards have to deal with both new and existing challenges, including encouraging wider awareness and adoption of these Standards, enhancing the harmonization effort, ensuring technical advances are captured in timely revisions to these Standards, and most pressing to ensure that the next generation of offshore engineers are encouraged to participate in the long-term development of the Standards that they will be using and questioning. This paper is one of a series of papers at this OMAE Conference that outline the technical content and future strategy of the ISO Offshore Structures Standards.

International Standards Used Locally Worldwide: Adopting ISO Standards for the (Offshore) Oil and Gas Industry As National Standard by 34 European Countries in a Single Process

2018 ◽  
Author(s):  
J. E. J. (Jarno) Dakhorst
Keyword(s):  
Oil And Gas ◽  
National Level ◽  
Oil And Gas Industry ◽  
Offshore Structures ◽  
International Standards ◽  
National Standards ◽  
European Countries ◽  
National Standard ◽  
Gas Industry ◽  
European Standards

Standardisation is the process of developing a standard at an international, regional or national level. The oil and gas industry welcomes international standards as tool to do its operations efficiently and responsibly, and to demonstrate to comply with regulations, where applicable. In this way, the oil and gas industry uses international standards as part of their licence to operate. Because the oil and gas industry is acting globally, it would like to prevent that they have to deal with different standards depending on the region or country in which they operate. Therefore, the oil and gas industry strives for international standards that are also adopted as national standards across the world. The European oil and gas industry supports this vision by adopting the international standards as European standards, which will then become the national standard as well in 34 European countries at once. Also in the field of offshore structures and more recently Arctic operations, international standards are being developed or revised to respond to the needs of the industry. These standardisation activities include European involvement to ensure alignment of the standards portfolio of the oil and gas industry.

Subsea Cable Stability on Rocky Seabeds: Comparison of Field Observations Against Conventional and Novel Design Methods

2018 ◽  
Author(s):  
Terry Griffiths ◽  
Scott Draper ◽  
Liang Cheng ◽  
Feifei Tong ◽  
Antonino Fogliani ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Power Transmission ◽  
Small Diameter ◽  
Oil And Gas Industry ◽  
Operational Reliability ◽  
Design Methods ◽  
Gas Industry ◽  
Integrity Management ◽  
Tidal Stream ◽  
Almost All

As offshore renewable energy projects progress from concept demonstration to commercial-scale developments there is a need for improved approaches beyond conventional cable engineering design methods that have evolved from larger diameter pipelines for the oil and gas industry. New approaches are needed to capture the relevant physics for small diameter cables on rocky seabeds to reduce the costs and risks of power transmission and increase operational reliability. This paper reports on subsea cables that MeyGen installed for Phase 1a of the Pentland Firth Inner Sound tidal stream energy project. These cables are located on rocky seabeds in an area where severe metocean conditions occur. ROV field observation of these cables shows them to be stable on the seabed with little or no movement occurring over almost all of the cable routes, despite conventional engineering methods predicting significant dynamic movement. We cite recent research undertaken by the University of Western Australia (UWA) to more accurately assess the hydrodynamic forces and geotechnical interaction of cables on rocky seabeds. We quantify the conformity between the cables and the undulating rocky seabed, and the distributions of cable-seabed contact and spanning via simulations of the centimetric-scale seabed bathymetry. This analysis leads to calculated profiles of lift, drag and seabed friction along the cable, which show that all of these load and reaction components are modelled in an over-conservative way by conventional pipeline engineering techniques. Overall, our analysis highlights that current cable stability design can be unnecessarily conservative on rocky seabeds. Our work foreshadows a new design approach that offers more efficient cable design to reduce project capex and enhance through-life integrity management.

scholarly journals ON STANDARDIZATION OF LABORATORY SOIL TESTING IN OFFSHORE GEOTECHNICAL SURVEY

Gruntovedenie ◽  
2021 ◽  
Vol 1 (16) ◽  
pp. 16-52
Author(s):  
E.A. Voznesensky ◽  
◽  
A.S. Loktev ◽  
M.S. Nikitin ◽  
◽  
...  
Keyword(s):  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Offshore Structures ◽  
Soil Testing ◽  
National Standard ◽  
Gas Industry ◽  
Code Of Practice ◽  
Complete Section ◽  
Testing Practice ◽  
Russian Soil

Issues of laboratory soil studies standardization in offshore geotechnical survey are discussed in connection with the end of expertise of two new regulative documents – new edition of the Code of practice and Russian national standard developed on the basis of international ISO standard. Since these documents of different level belong also to different categories (geotechnical survey and oil and gas industry), the authors analyze their interrelation and consistency, from one hand, and the preparedness of Russian soil testing practice to implementation of the new standard which results from harmonization with international ones, from the other. Complete section of the standard draft related to soil laboratory testing is presented, preceded by commentary on some important issues regarding the implementation of its specific methodic statements. It is concluded that the new national GOST draft «Petroleum and natural gas industries. Specific requirements for offshore structures. Marine soil investigations» developed on ISO basis will be a useful document supported in general by Russian normative base but expanding a possible range of voluntary methods into well time-tested foreign approaches. This documents can be considered to be a toolkit annex to the Code of practice describing testing approaches beyond the scope of typical tasks

scholarly journals Carboline’s systems approach to the maintenance of coating systems for steel structures in the oil and gas industry

2019 ◽  
Vol 121 ◽  
pp. 02003
Author(s):  
Gennadiy Konovalov
Keyword(s):  
Oil And Gas ◽  
Systems Approach ◽  
Protective Coatings ◽  
Surface Preparation ◽  
Steel Structures ◽  
Oil And Gas Industry ◽  
Internal Stresses ◽  
Gas Industry ◽  
Low Levels ◽  
Protective Systems

The article discusses options for optimal repair systems with several advantages compared with competitive solutions in the market of protective coatings. The proposed materials have a high tolerance to the degree of surface preparation, compatibility with old protective systems, as well as low levels of internal stresses arising in the repair layer of coating, which significantly reduces the risk of pulling off the old protective coatings after repair.

Digital innovation in subsea integrity management

2020 ◽  
Vol 60 (1) ◽  
pp. 215
Author(s):  
Ricky Thethi ◽  
Dharmik Vadel ◽  
Mark Haning ◽  
Elizabeth Tellier
Keyword(s):  
Domain Knowledge ◽  
Oil And Gas ◽  
Digital Technologies ◽  
Oil And Gas Industry ◽  
Gas Industry ◽  
Cost Efficiencies ◽  
Exploration And Production ◽  
Integrity Management ◽  
Offshore Oil And Gas ◽  
Dynamic Structures

Since the 2014 oil-price downturn, the offshore oil and gas industry has accelerated implementation of digital technologies to drive cost efficiencies for exploration and production operations. The upstream offshore sector comprises many interfacing disciplines such as subsurface, drilling and completions, facilities and production operations. Digital initiatives in subsurface imaging, drilling of subsea wells and topsides integrity have been well publicised within the industry. Integrity of the subsea infrastructure is one area that is currently playing catch up in the digital space and lends itself well for data computational efficiencies that artificial-intelligence technologies provide, to reduce cost and lower the risk of subsea equipment downtime. This paper details digital technologies employed in the area of subsea integrity management to meet the objectives of centralising access to critical integrity data, automating workflows to collect and assess data, and using machine learning to perform more accurate and faster engineering analysis with large volumes of field-measured data. A comparison of a typical subsea field is presented using non-digital and digital approaches to subsea integrity management (IM). The comparison demonstrates where technologies such as digital twins for dynamic structures, and auto anomaly detection by using image recognition algorithms can be deployed to provide a step change in the quality of subsea integrity data coming from field. It is demonstrated how the use of a smart IM approach, combined with strong domain knowledge in subsea engineering, can lead to cost efficiencies in operating subsea assets.

Stress Concentration Factors Calculation: Analytical and Numerical Approaches for Welded Tubular Joints

2020 ◽  
Author(s):  
Nathalia Paruolo ◽  
Thalita Mello ◽  
Paula Teixeira ◽  
Marco Pérez
Keyword(s):  
Stress Concentration ◽  
Oil And Gas ◽  
Hot Spot ◽  
Experimental Tests ◽  
Oil And Gas Industry ◽  
Offshore Structures ◽  
Gas Industry ◽  
Tubular Joints ◽  
Concentration Factors ◽  
Stress Concentration Factors

Abstract In the oil and gas industry, fixed platforms are commonly applied in shallow water production. In-place environmental conditions generates cyclic loads on the structure that might lead to structural degradation due to fatigue damage. Fatigue is one of the most common failure modes of offshore structures and is typically estimated when dimensioning of the structure during design phase. However, in times when life extension of existing offshore structures is being a topic in high demand by industry, mature fields may represent an interesting investment, especially for small companies. Concerning fixed platforms, composed mainly by welded tubular joints, the assessment of hot spot stresses is considered to predict structure fatigue. The estimation of welded joint hot spot stresses is based on the stress concentration factors (SCFs), which are given by parametric formulae, finite element analysis (FEA) or experimental tests. Parametric formulae may be defined as a fast and low-cost method, meanwhile finite elements analysis may be time consuming and experimental tests associated with higher costs. Given these different characteristics, each method is applied according to the study case, which will rely on the joint geometry and associated loads. Considering simple joint geometries several sets of parametric equations found in the literature may be applied. On the other hand, the SCFs calculation of non-studied yet complex joints consider known formulae adapted according to the under load joint behavior and geometry. Previous analysis shows that this adaptation may furnish different results compared to those obtained by FEA. Furthermore, it is observed that even for simple joints the results derived from the different methods may differ. Given their importance for the oil and gas industry, since they are the basis for the assessment of the fatigue life of welded tubular joints which may impact on additional costs related to maintenance and inspection campaigns, the estimation of SCFs must be the most accurate as possible. Therefore, this paper intends to investigate the differences between results derived from parametric formulae and different FEA studies.

Towards Implementing Condition-Based Maintenance (CBM) Policy for Offshore Blowout Preventer (BOP) System

2019 ◽  
Author(s):  
Tobiloba Elusakin ◽  
Mahmood Shafiee ◽  
Tosin Adedipe
Keyword(s):  
Oil And Gas ◽  
Cost Savings ◽  
Oil And Gas Industry ◽  
Condition Based Maintenance ◽  
Gas Industry ◽  
Training Requirements ◽  
Blowout Preventer ◽  
Integrity Management ◽  
Maintenance Personnel ◽  
Oil And Gas Companies

Abstract With the steadily growing demand for energy in the world, oil and gas companies are finding themselves facing increasing capital and operating costs. To ensure the economic viability of investments and improve the safety of operations, oil and gas companies are promoting their asset integrity management (AIM) systems. In the past, the oil and gas industry adopted reactive maintenance regimes, which involved recertification, testing and repair of faulty equipment while trying to achieve minimum downtime. As technology becomes more affordable, operators have been able to carry out improved fault diagnosis, prognosis and maintenance optimisation. As a result of this, condition-based maintenance (CBM) is being adopted more and more as the preeminent maintenance regime for oil and gas equipment. The blowout preventer (BOP) is one of the most expensive and safety critical drilling equipment in the oil and gas industry. However, there have been very few studies and best practices about how to develop a CBM policy and what specific monitoring techniques and devices will be required to implement it for the BOP system. This paper proposes a V-model based architecture for designing a CBM policy in BOP systems. As a result of the model proposed, gaps in implementation are identified and all the hardware, software and training requirements for implementing the CBM solution in BOP systems will be outlined in detail. Our proposed CBM framework will help BOP operators and maintenance personnel make cost savings through less repairs and replacements and minimal downtime.

Rationale for load specifications and load factors in the new CSA code for fixed offshore structures

1991 ◽  
Vol 18 (3) ◽  
pp. 454-464 ◽  
Author(s):  
Ian J. Jordaan ◽  
Marc A. Maes
Keyword(s):  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Offshore Structures ◽  
Limit States ◽  
Gas Industry ◽  
Offshore Installations ◽  
Load Factors ◽  
Annual Probability ◽  
Acceptable Risks ◽  
Economic Analyses

The Canadian Standards Association (CSA) initiated effort in 1984 aimed at the development of an offshore code for production structures in the oil and gas industry. The present paper summarizes the rationale behind the development of design load specifications in the preliminary standard S.471 "General requirements, design criteria, the environment, and loads." As part of this development, background calibration studies were conducted in tandem with the work of various committees. Selected results from these studies are also discussed in this paper. The basic objectives and tools for developing load criteria for the design of offshore installations are discussed. The use of economic analyses of cost versus safety of structures does not provide clear guidance, and the perspective taken is that of acceptable risks to an individual. This is used in the context of limit states design, which, in S.471, incorporates two safety classes. In order to provide consistent safety levels, the environmental loads are divided into categories based on frequent and rare occurrence, examples being waves and earthquakes, respectively. The role of the annual probability of failure in setting target levels of reliability as well as in the calibration process is emphasized. Various aspects of calibration are summarized, including the background to the rare-frequent separation of loads, the objective function used to optimize the results, as well as the method of handling model uncertainty. Key words: environment, limit states, loads, offshore, reliability, resistance, safety, structures.

Self Directed Integrity Assessment of Non-Piggable Pipelines

2015 ◽  
Author(s):  
Ashish Khera ◽  
Rajesh Uprety ◽  
Bidyut B. Baniah
Keyword(s):  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Management Plan ◽  
Gas Industry ◽  
Internal Corrosion ◽  
Integrity Assessment ◽  
Regulatory Standards ◽  
The Us ◽  
Integrity Management ◽  
External Corrosion

The responsibility for managing an asset safely, efficiently and to optimize productivity lies solely with the pipeline operators. To achieve these objectives, operators are implementing comprehensive pipeline integrity management programs. These programs may be driven by a country’s pipeline regulator or in many cases may be “self-directed” by the pipeline operator especially in countries where pipeline regulators do not exist. A critical aspect of an operator’s Integrity Management Plan (IMP) is to evaluate the history, limitations and the key threats for each pipeline and accordingly select the most appropriate integrity tool. The guidelines for assessing piggable lines has been well documented but until recently there was not much awareness for assessment of non-piggable pipelines. A lot of these non-piggable pipelines transverse through high consequence areas and usually minimal historic records are available for these lines. To add to the risk factor, usually these lines also lack any baseline assessment. The US regulators, that is Office of Pipeline Safety had recognized the need for establishment of codes and standards for integrity assessment of all pipelines more than a decade ago. This led to comprehensive mandatory rules, standards and codes for the US pipeline operators to follow regardless of the line being piggable or non-piggable. In India the story has been a bit different. In the past few years, our governing body for development of self-regulatory standards for the Indian oil and gas industry that is Oil Industry Safety Directorate (OISD) recognized a need for development of a standard specifically for integrity assessment of non-piggable pipelines. The standard was formalized and accepted by the Indian Ministry of Petroleum in September 2013 as OISD 233. OISD 233 standard is based on assessing the time dependent threats of External Corrosion (EC) and Internal Corrosion (IC) through applying the non-intrusive techniques of “Direct Assessment”. The four-step, iterative DA (ECDA, ICDA and SCCDA) process requires the integration of data from available line histories, multiple indirect field surveys, direct examination and the subsequent post assessment of the documented results. This paper presents the case study where the Indian pipeline operators took a self-initiative and implemented DA programs for prioritizing the integrity assessment of their most critical non-piggable pipelines even before the OISD 233 standard was established. The paper also looks into the relevance of the standard to the events and other case studies following the release of OISD 233.

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