Value of Reliability, Availability and Maintainability (RAM) Simulation Models in Pipeline Systems

2016 ◽  
Author(s):  
Bradley M. Jones ◽  
André-Michel Ferrari
Keyword(s):  
Oil And Gas ◽  
Block Diagram ◽  
Discrete Event ◽  
Simulation Models ◽  
Cost Effective ◽  
Business Environment ◽  
Pipeline System ◽  
Throughput Optimization ◽  
Design Standards ◽  
Cost Avoidance

Reliability, Availability and Maintainability (RAM) models were first developed in Enbridge Liquids Pipelines in 2006 and in the last 3 years have contributed over $200 Million in capital cost avoidance while maintaining or improving the reliable design and operation of the pipeline system. These models constitute a very effective, factual and dependable tool to assess the throughput performance of a pipeline system over its entire life cycle or a specified time of interest. In addition, the RAM model cost is a small fraction of the overall monetary benefit, in the order of 1%, hence making RAM models a highly leveraged activity. The concept of a RAM model stems from Reliability Block Diagram methods (also known as Dependent Diagrams). Interaction of large, complex and multi layered systems can then be analyzed using the Monte Carlo simulation methods (or Stochastic Discrete Event Simulation) hence quantifying the output of the entire system with greater accuracy than other estimating tools or methods. Over 10 years, Enbridge Liquids Pipelines has developed its own failure database for equipment and operational events consequently almost all model inputs are based on in-house data rather than industry generic data, making the model output more robust, accurate and appropriate for internal use. Initially, in Enbridge Liquids Pipelines, RAM models were mainly built to assess and confirm the design capabilities of future pipelines designs and assist in the optimal selection of specific design options. Because of the effectiveness of the tool combined with the current cost constrained business environment, the company is moving towards building RAM models for assets already in operation in order to optimize their performance. This is proving to be an extremely cost effective addition to internal decision making processes. The approach has been used in risk based budgeting, asset maintenance, design modifications and throughput optimization initiatives. In various industries including Oil and Gas, RAM models have proven their worth over time as an effective cost avoidance tool. This approach has now been successfully deployed in the Pipeline Industry at Enbridge. As an example, a RAM model conducted during the design phase of a pipeline project saved $28 million in capital by proving that an additional storage tank and significant new infrastructure was not required. Another benefit of RAM models has been their ability to confirm or counter stated assumptions by internal stakeholders. Equipment upgrades and equipment sparing decisions are often seriously debated and costly decisions may not always be based on complete economical foundations but rather on avoiding past negative experiences or by following basic guidelines that are less than optimal. When a project or operational team needs to find an alternative, a RAM model is a tool of choice to evaluate, and justify the best option. Because of its proven value, RAM models are now an integral part of Enbridge Liquids Pipelines Design Standards and are used on all large projects. Models recently built for operational pipelines delivered similar value so in the near future the work will be expanded to encompass the entire existing network of integrated pipelines to improve on performance and operational costs.

Best Practices for the Design and Installation of Bolted Joints

2004 ◽  
Author(s):  
Debra Tetteh-Wayoe
Keyword(s):  
Best Practices ◽  
Oil And Gas ◽  
Cost Effective ◽  
Field Testing ◽  
Oil And Gas Industry ◽  
Bolted Joints ◽  
Pipeline System ◽  
Technical Literature ◽  
Operational Life ◽  
Welded Pipe

The cost effective design and construction of liquid pipeline facilities traditionally necessitates the use of bolted joints as opposed to welds. Some of these bolted joints are frequently disassembled and reassembled as part of regular maintenance, while others are assembled at the time of construction and expected to retain a seal for the lifetime of the pipeline. Consequently, the design and installation practices employed for bolted connections are relied upon to produce the same operational life and integrity as welded pipe. In an effort to ensure that the bolted joints used on our pipeline system are as reliable as our welded joints, we investigated industry best practices for flange assembly and the root causes of joint failure. We have completed extensive research of technical literature, including the torquing procedures used in various industries, and performed field-testing on our own system. Generally we have found that: • Flange assembly failures and concerns about this issue are common in the oil and gas industry; • Practices for tightening flanges are inconsistent; and • To accomplish and retain an effective gasket seal, and thus minimize life cycle leaks, one has to consider many factors, including the amount of torque applied to nuts, the stud and nut friction, the type of gasket used, the size of the studs/nuts/flanges, the type of equipment used for tightening, the calibration of the torquing equipment, flange face alignment, and torquing sequence. Using the results of our investigation, we implemented several measures to enhance both the quality and the long-term integrity of our bolted flange connections. This paper describes the results of our investigations, as well as the practices implemented for flange assemblies required for maintenance and new construction activities.

Integrated production modelling of the Wheatstone-Iago fields: boon or bane?

2012 ◽  
Vol 52 (2) ◽  
pp. 639
Author(s):  
Gbenga Afuape ◽  
Myles Regan ◽  
Ronald May ◽  
Vernon Roewer ◽  
Anton Chung ◽  
...  
Keyword(s):  
Large Scale ◽  
Oil And Gas ◽  
Simulation Models ◽  
Oil And Gas Industry ◽  
Pipeline System ◽  
Gas Industry ◽  
Full Field ◽  
Integrated Production ◽  
Surface Network ◽  
Production Modelling

Applying integrated production modelling (IPM) for decision making in the oil and gas industry has proliferated rapidly, evidenced by the amount of published information about successful applications of this approach. A reason for its popularity is to mitigate the risk of over(under)investment, which is driving asset teams toward jettisoning the practice of using fixed THP to account for backpressure effects or to use the limited surface network options available in most numerical reservoir simulators. This extended abstract describes the modelling of an offshore gas development by coupling multiple full-field, numerical reservoir simulation models with a shared surface network model. Such an approach enabled subsurface elements of the production system to be linked directly to surface elements (subsea and platform) yielding a fully coupled IPM. Key development decisions were tested and justified in a technically rigorous and economically robust manner. These decisions included the phasing of development wells, compression requirements and flow balancing in the pipeline system to maintain specified gas delivery rates. Experience from this approach has shown traditional reservoir engineering techniques can still yield the same outcome as an IPM with comparable accuracy—for some development decisions such as using a creaming curve and fixed THP to determine optimum well count; nevertheless, using simple methods to account for backpressure effects may not allow the same broad-based integration of design requirements needed at the design and engineering stage of large-scale projects. The PowerPoint presentation is not available to APPEA.

Qualification Testing of Mechanical Pipe Joining Method

2014 ◽  
Author(s):  
Dave McColl ◽  
Adam Whiting
Keyword(s):  
Oil And Gas ◽  
Cost Effective ◽  
Operating Conditions ◽  
Performance Criteria ◽  
Innovative Technology ◽  
Pipeline System ◽  
Internal Corrosion ◽  
Regulatory Standards ◽  
Cost Effective Method ◽  
Pipeline Failures

Pipeline infrastructure is the backbone of the energy industry and remains the safest and most cost effective method for transporting oil and gas. For decades corrosion has presented a significant challenge to pipeline operators. According to Alberta Energy Regulator data, internal corrosion is considered to be the root cause for more than 54% of all documented pipeline failures in Alberta [1]. Spoolable composite pipeline technologies have become a mainstream corrosion solution over the last 10 years, however these products are limited to smaller pipelines, typically less than 6 inches in diameter. Traditional slip-lining (field installed plastic lined steel pipe) is used for internal corrosion protection of larger pipelines, however it is costly, requiring labour intensive field construction, often completed in inhospitable environmental conditions. As a result project delays and cost over-runs are commonplace. Recognizing the need for a cost effective pipeline corrosion solution for larger gathering pipelines, an innovative technology was developed that combines a unique mechanical pipe joining system with an integrated electro-fusion coupler. The new joining system enables insertion of an HDPE liner in a factory environment where costs and quality can be tightly controlled. The new joining system eliminates conventional welding of the pipeline in the field and instead uses a custom field press to quickly energize the mechanical pipe joint. Field scope is significantly reduced, construction completed in less time, and associated costs greatly reduced. This paper discusses the testing completed to qualify the new joining system for use in oilfield gathering pipelines. The qualification test plan includes all requirements identified in applicable regulatory standards (primarily CSA Z662-11), and prudent engineering requirements based on anticipated field handling and anticipated operating conditions. The test regime was ultimately designed to ensure the suitability of the pipeline system for intended service. Testing included hydrostatic burst, static gas pressure, bend, cyclic pressure and thermal, vacuum, tensile, and compressive tests on the joint. The test results show that in all cases the jointing system successfully met the established design performance criteria and in most cases exceeded the actual mechanical properties of the parent pipe, thus proving the joining system ready for field installations.

Material Challenges in Arctic Areas

2007 ◽  
Author(s):  
Agnes Marie Horn ◽  
Per Egil Kvaale ◽  
Mons Hauge
Keyword(s):  
Low Temperature ◽  
Oil And Gas ◽  
Material Selection ◽  
Low Cost ◽  
Cost Effective ◽  
Structural Steels ◽  
Cold Climate ◽  
International Standards ◽  
Pipeline System ◽  
Oil And Gas Exploration

There is a lack of rules and standards that provide guidelines for material selection and qualification of materials for offshore and onshore structures in arctic areas. Many current standards for low temperature applications such as cryogenic piping and process systems do not reflect the need for low-cost bulk materials for large volume applications such as pipelines and production facilities. The growing focus on oil and gas exploration in arctic areas has raised the need for new standards and industry practice that supports cost effective and safe installation and operation of production and transport facilities in the cold climate. There are materials today that are applicable for low temperature conditions. The grades are often highly alloyed (typically 3–9% Ni) with good toughness properties, but these alloys are expensive compared to conventional steel material grades. Such materials may not be applicable in pipelines, structures and process plants. This challenge can be met in two ways. First, structural steels that are capable of being welded and operated in the cold climate should be developed and qualified. Second, materials for forged and casted components that can be welded to the structural steels should be developed and qualified to fit into the integrated structure or pipeline system. Some actions have been taken to develop new standards e.g. within ISO19906, and actions are being taken in Russia to harmonize their specifications with the international standards, but this is a comprehensive job and the work must be executed in parallel with the development of new steels and welding technology.

Technology transfer from British to Vietnamese industrial companies - venturing into a new business culture

2018 ◽  
Vol 34 (2) ◽  
Author(s):  
Ca Tran Ngoc
Keyword(s):  
Technology Transfer ◽  
Transfer Process ◽  
Oil And Gas ◽  
Service Industry ◽  
Oil And Gas Industry ◽  
Business Environment ◽  
Background Information ◽  
Business Culture ◽  
Industrial Companies ◽  
New Business

The paper examines the process of technology transfer from British industrial companies to Vietnamese companies, to look at the obstacles of this process, especially in dealing with different business culture environments. The study uses the case studies method, conducting interviews with about ten companies working in oil and gas service industry. Since this is only a first stage of the longer term project, only preliminary results were discussed. Therefore, a company in civil engineering consulting has been examined for comparison. The paper argues that the differences in perception of the same operation activity like service in oil and gas industry are crucial factors to take into account if the transfer process is to be successful. Also, the transferor and the recipient may have different behaviour in negotiating, in communicating with each other. Thus, the preparation of background information, to do "home work", patience and pro-active attitudes in trying to understand partners are important for transferring technology into different business environment.   In addition, the factors, sometime not very technology-related, such as internal political motives and organisational issues of the firms involved can be very influential in the success of technology transfer process.

Sand Free Production Success Through Proven Technology Enabler from An Untapped Heterogeneous Reservoir Zone Utilizing Gravel Pack Replacement Methodology

2020 ◽  
Author(s):  
Y. Anggoro
Keyword(s):  
Oil And Gas ◽  
Erosion Resistance ◽  
Cost Effective ◽  
High Rate ◽  
Screen Design ◽  
Sand Control ◽  
Rules Of Thumb ◽  
Production Success ◽  
Control Technologies ◽  
Gravel Pack

The Belida field is an offshore field located in Block B of Indonesia’s South Natuna Sea. This field was discovered in 1989. Both oil and gas bearing reservoirs are present in the Belida field in the Miocene Arang, Udang and Intra Barat Formations. Within the middle Arang Formation, there are three gas pay zones informally referred to as Beta, Gamma and Delta. These sand zones are thin pay zones which need to be carefully planned and economically exploited. Due to the nature of the reservoir, sand production is a challenge and requires downhole sand control. A key challenge for sand control equipment in this application is erosion resistance without inhibiting productivity as high gas rates and associated high flow velocity is expected from the zones, which is known to have caused sand control failure. To help achieve a cost-effective and easily planned deployment solution to produce hydrocarbons, a rigless deployment is the preferred method to deploy downhole sand control. PSD analysis from the reservoir zone suggested from ‘Industry Rules of Thumb’ a conventional gravel pack deployment as a means of downhole sand control. However, based on review of newer globally proven sand control technologies since adoption of these ‘Industry Rules of Thumb’, a cost-effective solution could be considered and implemented utilizing Ceramic Sand Screen technology. This paper will discuss the successful application at Block B, Natuna Sea using Ceramic Sand Screens as a rigless intervention solution addressing the erosion / hot spotting challenges in these high rate production zones. The erosion resistance of the Ceramic Sand Screen design allows a deployment methodology directly adjacent to the perforated interval to resist against premature loss of sand control. The robust ceramic screen design gave the flexibility required to develop a cost-effective lower completion deployment methodology both from a challenging make up in the well due to a restrictive lubricator length to the tractor conveyancing in the well to land out at the desired set depth covering the producing zone. The paper will overview the success of multi-service and product supply co-operation adopting technology enablers to challenge ‘Industry Rules of Thumb’ replaced by rigless reasoning as a standard well intervention downhole sand control solution where Medco E&P Natuna Ltd. (Medco E&P) faces sand control challenges in their high deviation, sidetracked well stock. The paper draws final attention to the hydrocarbon performance gain resulting due to the ability for choke free production to allow drawing down the well at higher rates than initially expected from this zone.

Cost Avoidance and Clinical Benefits Derived from a Pharmacy-Managed Anemia Program

2000 ◽  
Vol 35 (2) ◽  
pp. 169-175 ◽  
Author(s):  
Robert A. Quercia ◽  
Ronald Abrahams ◽  
C. Michael White ◽  
John D'Avella ◽  
Mary Campbell
Keyword(s):  
Cost Savings ◽  
Cost Effective ◽  
Hemodialysis Patients ◽  
Cost Avoidance ◽  
Number Of Patients ◽  
Epoetin Alpha ◽  
Clinical Benefits ◽  
Unit Dose ◽  
One Year ◽  
Alpha Therapy

A pharmacy-managed anemia program included distribution and clinical components, with the goal of making epoetin alpha therapy for hemodialysis patients more cost-effective. The Pharmacy Department prepared epoetin alpha doses for patients in unit-dose syringes, utilizing and documenting vial overfill. Pharmacists dosed epoetin alpha and iron (oral and intravenous) per protocol for new and established patients. Baseline data were obtained in 1994, one year prior to implementation of the program, and were re-evaluated in 1995 and 1998. Cost avoidance from utilization of epoetin alpha vial overfill in 1995 and 1998 was $83,560 and $91,148 respectively. In 1995 and 1998, cost avoidance from pharmacy management of anemia was $191,159 and $203,985 respectively. The total cost avoidance from 1995 through 1998 was estimated at $1,018,638. The number of patients with hematocrits under 31% decreased from 32% in 1994 to 21% and 14% in 1995 and 1998 respectively. We conclude that a pharmacy-managed anemia program for hemodialysis patients results in significant cost savings and better achievement of target hematocrits.

scholarly journals Simulation modeling and analysis of primary health center operations

SIMULATION ◽  
2021 ◽  
pp. 003754972110309
Author(s):  
Mohd Shoaib ◽  
Varun Ramamohan
Keyword(s):  
Resource Utilization ◽  
Waiting Times ◽  
Discrete Event ◽  
Simulation Models ◽  
Modeling And Analysis ◽  
Healthcare Facilities ◽  
Event Simulation ◽  
Analytical Approximations ◽  
Primary Health ◽  
Generic Modeling

We present discrete-event simulation models of the operations of primary health centers (PHCs) in the Indian context. Our PHC simulation models incorporate four types of patients seeking medical care: outpatients, inpatients, childbirth cases, and patients seeking antenatal care. A generic modeling approach was adopted to develop simulation models of PHC operations. This involved developing an archetype PHC simulation, which was then adapted to represent two other PHC configurations, differing in numbers of resources and types of services provided, encountered during PHC visits. A model representing a benchmark configuration conforming to government-mandated operational guidelines, with demand estimated from disease burden data and service times closer to international estimates (higher than observed), was also developed. Simulation outcomes for the three observed configurations indicate negligible patient waiting times and low resource utilization values at observed patient demand estimates. However, simulation outcomes for the benchmark configuration indicated significantly higher resource utilization. Simulation experiments to evaluate the effect of potential changes in operational patterns on reducing the utilization of stressed resources for the benchmark case were performed. Our analysis also motivated the development of simple analytical approximations of the average utilization of a server in a queueing system with characteristics similar to the PHC doctor/patient system. Our study represents the first step in an ongoing effort to establish the computational infrastructure required to analyze public health operations in India and can provide researchers in other settings with hierarchical health systems, a template for the development of simulation models of their primary healthcare facilities.

Gas pipeline leakage detection in the presence of parameter uncertainty using robust extended Kalman filter

2021 ◽  
pp. 014233122198911
Author(s):  
Mohadese Jahanian ◽  
Amin Ramezani ◽  
Ali Moarefianpour ◽  
Mahdi Aliari Shouredeli
Keyword(s):  
Kalman Filter ◽  
Extended Kalman Filter ◽  
Parameter Uncertainty ◽  
Oil And Gas ◽  
Estimation Error ◽  
Real Data ◽  
Gas Pipeline ◽  
Pipeline System ◽  
Parameter Uncertainties ◽  
Simulation Results

One of the most significant systems that can be expressed by partial differential equations (PDEs) is the transmission pipeline system. To avoid the accidents that originated from oil and gas pipeline leakage, the exact location and quantity of leakage are required to be recognized. The designed goal is a leakage diagnosis based on the system model and the use of real data provided by transmission line systems. Nonlinear equations of the system have been extracted employing continuity and momentum equations. In this paper, the extended Kalman filter (EKF) is used to detect and locate the leakage and to attenuate the negative effects of measurement and process noises. Besides, a robust extended Kalman filter (REKF) is applied to compensate for the effect of parameter uncertainty. The quantity and the location of the occurred leakage are estimated along the pipeline. Simulation results show that REKF has better estimations of the leak and its location as compared with that of EKF. This filter is robust against process noise, measurement noise, parameter uncertainties, and guarantees a higher limit for the covariance of state estimation error as well. It is remarkable that simulation results are evaluated by OLGA software.

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