Probabilistic Methods for Predicting the Remaining Life of Offshore Pipelines

2017 ◽  
Vol 139 (4) ◽  
Author(s):  
Alireda Aljaroudi ◽  
Premkumar Thodi ◽  
Ayhan Akinturk ◽  
Faisal Khan ◽  
Mike Paulin
Keyword(s):  
Environmental Hazard ◽  
Decision Makers ◽  
Probabilistic Methods ◽  
Remaining Life ◽  
Offshore Pipelines ◽  
Design Life ◽  
Potential Safety ◽  
Oil Flow ◽  
Safety And Reliability ◽  
Extended Operation

When offshore pipelines approach the end of their design life, their condition could threaten oil flow continuity as well as become a potential safety or environmental hazard. Hence, there is a need to assess the remaining life of pipelines to ensure that they can cope with current and future operational demand and integrity challenges. This paper presents a methodology for assessing the condition of aging pipelines and determining the remaining life that can support extended operation without compromising safety and reliability. Applying this methodology would facilitate a well-informed decision that enables decision makers to determine the best strategy for maintaining the integrity of aging pipelines.

Application of Probabilistic Methods for Predicting the Remaining Life of Offshore Pipelines

2014 ◽  
Author(s):  
Alireda Aljaroudi ◽  
Premkumar Thodi ◽  
Ayhan Akinturk ◽  
Faisal Khan ◽  
Mike Paulin
Keyword(s):  
Oil And Gas ◽  
Probabilistic Methods ◽  
Assessment Process ◽  
Pipeline System ◽  
Remaining Life ◽  
Operating Characteristics ◽  
Offshore Pipelines ◽  
Design Life ◽  
Course Of Action ◽  
Oil Flow

When offshore pipelines are approaching the end of their design life or have gone beyond their design life, their condition could possibly threaten oil flow continuity (through leak or rupture) as well as become a potential safety or environmental hazard. Some of the pipelines may show signs of deterioration and ageing due to corrosion, cracking or other damage mechanisms. Any assets, such as the pipeline, may be desired to continue transporting hydrocarbons beyond its design life due to increased oil and gas demand, due to unforeseen increased oil and gas reserves, or due to upgrade where additional assets are tied-into the existing pipeline system. Other situations may force operators to maintain the pipeline’s design life in spite of premature ageing of the pipe wall caused by the increased corrosion growth or other anomalies. Hence, there may be a need to assess the remaining life of pipeline in order to determine if it is capable of coping with current and future operational demand. The first task in the assessment process is to identify degradation mechanisms and their rate of growth, then estimate uncertainties in the collected data concerning pipeline flaw geometry, pipeline mechanical properties and operating characteristics. Based on the collected data and the assessment, the probability and consequence of failure can be determined. The remaining life of a pipeline is the time it takes the pipeline to fail or exceed the target failure probability. This paper presents a methodology for assessing the condition of ageing pipelines and determining the remaining life that supports extended operation without compromising safety and reliability. Applying this methodology would facilitate a well-informed decision that enables decision makers to determine the best strategy or adequate course of action for assessing and maintaining the integrity of ageing pipelines.

Late life management of onshore and offshore pipelines

2015 ◽  
Vol 55 (2) ◽  
pp. 414
Author(s):  
Brian Humphreys ◽  
Wacek Lipski
Keyword(s):  
Oil And Gas ◽  
Life Review ◽  
Remaining Life ◽  
Offshore Pipelines ◽  
Field Development ◽  
Design Life ◽  
Inspection And Maintenance ◽  
1960S And 1970S ◽  
The 1960S ◽  
Opening Up

The Australian oil and gas boom of the 1960s and 1970s lead to production commencing in the Gippsland, Surat, Cooper and Carnarvon basins and so many pipeline assets around Australia are approaching operating lives of 40-50 years and the end of their design lives. With unconventional field development and the Australian gas markets opening up to international customers through LNG, there will be an increasing requirement to extend the life of pipelines while maintaining safety and integrity. The management of pipeline assets late in their design life is a challenge for operators both onshore and offshore, with pipelines requiring higher levels of inspection and maintenance, while revenues can be fixed or regulated for downstream assets or potentially declining for upstream assets. To operate pipelines beyond their specified design life, there are requirements that must be fulfilled—for offshore, a design re-qualification in accordance with DNV-OS-F101 and for onshore, a remaining life review in accordance with AS2885.3. In addition, for onshore pipelines, AS2885.3 requires the remaining life review process to be undertaken every 10 years, rather than just at the end of the design life. This extended abstract discusses the requirements of the DNV-OS-F101 and AS2885.3 and the approaches required to meet these requirements. It also discusses key lessons that have been learned and makes recommendations to pipeline operators preparing for end-of-design-life reviews and executing them as cost effectively as possible.

Remaining Life Assessment and Life Extension of Offshore Pipelines

2018 ◽  
Author(s):  
Jens P. Tronskar
Keyword(s):  
Life Assessment ◽  
Life Extension ◽  
Remaining Life ◽  
Original Design ◽  
Offshore Pipelines ◽  
Field Development ◽  
Design Life ◽  
The Future ◽  
Cost Efficient ◽  
Remaining Life Assessment

Cost efficient offshore field development often involves tiebacks to existing field infrastructure. Efficient field development requires life extension of existing production facilities and pipelines to accommodate the new field resources over their life expectation. For fields near the tail end of their production the pipelines may be close to the end of their design life, and it must be shown that they have potential for extended life beyond the original design life until the end of the period of operation of the new field. Offshore pipelines are designed and constructed to recognized standards, such as the widely applied DNV OS-F101 2013 Submarine Pipelines Systems and earlier versions. The latest edition of the code was recently issued as a standard with some major updates and a modified code number i.e. DNVGL ST-F101 [1]. As pipelines age, they will inevitably be exposed to various types of degradation and an Operator must be able to both assess the significance of this damage and the pipeline remaining life to ensure that the pipelines do not fail as they age before the end of their design lives. Currently, many pipelines are operated far beyond the original design life and as mentioned above for cost efficient field development the pipeline operator often needs to demonstrate that the pipeline’s useful life can be extended another 10 or in some cases up to 30 years. For some pipelines, new operating conditions will be introduced by tie-in of new fields and this will impact the future rate of degradation. Hence, it cannot be assumed that the future degradation will be similar or less severe than experienced since commissioning of the pipeline. Extension of the life of the pipeline can be demonstrated by adopting methods of analysis that show the line is safe for an extended life under the future expected operating condition. This paper describes the risk based approach applied for pipeline remaining life and life extension analyses based on DNV GL codes and other relevant recommended practices. For illustration of the methodology a typical case of remaining life assessment of and life extension of a gas export pipeline is presented in the Case Study.

Hydrogen’s Peculiar Effect on Material Properties: Do We Need to Be Concerned About Hydrogen Transport in Pipelines?

2021 ◽  
Author(s):  
Erling Østby ◽  
Bjørn-Andreas Hugaas ◽  
Agnes Marie Horn
Keyword(s):  
Mechanical Properties ◽  
Material Properties ◽  
Reliable Data ◽  
Hydrogen Gas ◽  
Decision Makers ◽  
Hydrogen Transport ◽  
Offshore Pipelines ◽  
Vast Number ◽  
Technical Aspects ◽  
Controversial Topic

Abstract Considering the vast number of articles that have been published during the last 150 years related to hydrogen embrittlement and the multiple attempts to explain the governing mechanisms, it is evident that hydrogen’s effect on mechanical properties in steel is still a controversial topic. This little atom has even by some authors been referred to as the “little devil”. We do not intend to explore this particular description of hydrogen any further. However, we would like to shed some light on the key technical aspects we believe need to be further scrutinized and understood to ensure that the decision-makers have sufficiently reliable data available to decide whether hydrogen gas can be safely transported in new or existing offshore pipelines at an acceptable cost.

Use of Fracture Mechanics Methods for Establishing Inspection Level for Turbine Wheels

1979 ◽  
Vol 101 (1) ◽  
pp. 75-79 ◽  
Author(s):  
R. E. Frishmuth
Keyword(s):  
Fracture Mechanics ◽  
Ferritic Steels ◽  
Remaining Life ◽  
Turbine Wheel ◽  
Complex Issue ◽  
General Application ◽  
Linear Elastic ◽  
Safety And Reliability ◽  
Elastic Fracture ◽  
Non Destructive

The establishment of inspection criteria for wheels in rotating machinery is frequently a complex issue. On one hand, safety and reliability of the parts and equipment must be assured while on the other, economical use must be made of available materials. In addition to these often opposing criteria, account must be taken of the limitations and cost of non-destructive evaluation methods. One way of considering all these factors and establishing safe inspection and acceptance criteria for wheels is to employ linear elastic fracture mechanics (LEFM) methods. The purpose of this paper is to outline a method for using LEFM to establish allowable stress levels or fracture toughness required in turbine wheel ferritic steels. The methods proposed are discussed in schematic fashion and it is shown that general application of a single “design curve” to many situations is possible if accuracy in specific cases is sacrificed. If this sacrifice is made so that results are conservative then the resulting plots can be used during the design of the wheel, the acceptance of a part or the evaluation of remaining life of an in-service wheel.

Industrial Remote Control System Based on C8051F120

2015 ◽  
Vol 743 ◽  
pp. 176-179
Author(s):  
Hong He ◽  
Xiao Jun Xu ◽  
Zhi Hong Zhang ◽  
Cheng Qian Mao
Keyword(s):  
Control System ◽  
Remote Control ◽  
Communication Theory ◽  
Wireless Transmission ◽  
Climbing Robot ◽  
Single Chip ◽  
Long Distance ◽  
Remote Control System ◽  
Potential Safety ◽  
Safety And Reliability

In order to solve the potential safety risk of traditional industrial remote control, a deep research on embedded and wireless communication theory has been done and a wireless remote control system with the C8051F120 single chip as the main control chip has been invited. Data can be sent and received steadily between transmitting terminal and receiving terminal in this system even in unfavorable environment, which largely improves the safety and reliability for long-distance operation. This system, with the feature of small size, easy installment, low power consumption and excellent wireless transmission, can be applied to industrial machinery such as pump car and wall-climbing robot.

INCREASING OIL FLOW CAPACITY IN EXTENDED OPERATION PIPELINES IN THE CONDITIONS OF LOW MONEY AND TIME COSTS

2017 ◽  
pp. 116-121
Author(s):  
V. I. Surikov
Keyword(s):  
High Efficiency ◽  
Operating Pressure ◽  
Time Costs ◽  
Flow Capacity ◽  
Main Pipelines ◽  
Oil Flow ◽  
Extended Operation

An instruction for implementing the increase in the capacity of main pipelines to restore operating pressure has been developed. The implementation of these methods in «Transneft» has shown high efficiency.

Introduction and Overview

1989 ◽  
pp. 1-20
Keyword(s):  
Power Plants ◽  
Failure Modes ◽  
Failure Criteria ◽  
Operating Conditions ◽  
Life Assessment ◽  
Remaining Life ◽  
Long Term Effects ◽  
Remaining Service Life ◽  
Design Life ◽  
Remaining Life Assessment

Abstract The ability to accurately assess the remaining life of components is essential to the operation of plants and equipment, particularly those in service beyond their design life. This, in turn, requires a knowledge of material failure modes and a proficiency for predicting the near and long term effects of mechanical, chemical, and thermal stressors. This chapter presents a broad overview of the types of damage to which materials are exposed at high temperatures and the approaches used to estimate remaining service life. It explains how operating conditions in power plants and oil refineries can cause material-related problems such as embrittlement, creep, thermal fatigue, hot corrosion, and oxidation. It also discusses the factors and considerations involved in determining design life, defining failure criteria, and implementing remaining-life-assessment procedures.

Integrity Management and Life Extension for a CALM Buoy Oil Export Terminal

2016 ◽  
Author(s):  
Robert B. Gordon ◽  
Juan Carlos Ruiz-Rico ◽  
Michiel Peter Hein Brongers ◽  
Julian Gomez
Keyword(s):  
Failure Modes ◽  
State Of The Art ◽  
Life Extension ◽  
Remaining Life ◽  
Integrity Assessment ◽  
Design Life ◽  
Oil Export ◽  
Integrity Management ◽  
Inspection And Maintenance ◽  
Future Risk

This paper applies state-of-the-art integrity management and life extension methodologies to address degradation and failure modes specific to CALM buoy export terminals. The main objectives are to (1) classify the components of the export terminal according to their criticality, (2) establish risk-based inspection and maintenance plans to reduce or mitigate risk to acceptable levels and (3) assess remaining life. The method is applied to a CALM buoy operating off the coast of Colombia. This buoy serves as the oil export terminal for all crude oil transmitted by the Ocensa pipeline, which has a capacity of 560 kBPD or around 60% of total Colombia oil production. The buoy is nearing the end of its design life, and options for life extension have been investigated based on an integrity assessment of the current condition of the equipment. As part of the assessment, detailed plans for future Risk Based Inspections (RBI) and Mitigation, Intervention, and Repair (MIR) have been developed.

Life-Cycle Management of Pressurized Fixed Equipment

2011 ◽  
Author(s):  
David A. Osage ◽  
David R. Thornton ◽  
Philip A. Henry
Keyword(s):  
Life Cycle ◽  
Damage Mechanism ◽  
Life Cycle Management ◽  
Remaining Life ◽  
Analysis Techniques ◽  
Design Life ◽  
Process Plants ◽  
Integrate Technology ◽  
Potential Damage ◽  
Service Inspection

Many process plants will continue to operate pressurized equipment well beyond its intended design life. To ensure that the equipment operates safely and reliably requires adoption of an equipment Life-Cycle Management (LCM) process. During equipment design the LCM process requires identification of potential damage mechanisms, and a design that resists or mitigates the damage. For equipment that has been put into operation the LCM process continues with the use of prescriptive or Risk-Based inspection. An evaluation of the in-service inspection results reveals whether any anticipated (i.e., was considered in the initial design) or unanticipated damage has occurred. If the damage is anticipated and within the design limits, the equipment is returned to operation for a period of time that considers the equipment remaining life, with a new inspection at the end of the operational period. If unanticipated damage is discovered the LCM process requires identification of the damage mechanism and a subsequent Fitness-For-Service assessment to facilitate a decision to run as is, or to rerate, repair, or to replace the damaged components. To effectively implement the LCM approach, codes and standards must exist that address each aspect of the process. In addition, ensuring that similar analysis techniques are employed at the time of construction and when conducting in-service assessments requires coordination of the technology integration in these codes and standards. An overview of API, ASME, and other codes and standards is provided together with a discussion of the efforts to integrate technology to support the LCM process.

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