Unpiggable Pipelines Integrity Assessment by Internal Corrosion Modelling bnd Prediction Based on Topside Piping Inspection Data in The Mature Field Offshore North West Java

2021 ◽  
Author(s):  
D. Iskandar
Keyword(s):  
Corrosion Rate ◽  
Solid Particles ◽  
West Java ◽  
Internal Corrosion ◽  
North West ◽  
Integrity Assessment ◽  
Corrosion Model ◽  
Integrity Management ◽  
Inspection Data ◽  
Fluid Sampling

Pertamina Hulu Energi - Offshore North West Java, also known as PHE ONWJ, owns 426 subsea pipelines from which only 185 are active operating to support the PHE ONWJ’s production activity and the remaining 241 pipelines are inactive which their status is either remain idle or being preserved. Noted that 67% or 284 of the pipelines aged more than its design life. Onehundred twenty pipelines are still actively operating distributing fluids such as Oil, Gas and 3-phase. Based on the observation, more than 90% of leak events occurred by internal corrosion, that causedby the corrosive agents such high CO2 content, sands or solid particles, SRB and water. The existing integrity management plan such as in-line inspection, fluid sampling, chemical injection and others were performed onto several pipelines. However, PHE ONWJ’s pipeline network facility on Figure 1-2 that is complex and massive, for that reason is not economically to perform in-line inspection to all pipelines. Considering to the conditions mentioned, an effective and efficient pipeline integrity management is developed based on corrosion rate prediction from topside piping within pipeline corrosion circuit as per API 571. This model is constructed from the combination of several parameters like fluid sampling, In-Line Inspection of several pipelines with different services, Topside piping inspection data, Operating history and Design data. The internal corrosion model is developed continuously to validate and used to assess data obtained from In-Line Inspection (ILI) that performed into several pipelines. Since the model is developed, the accuracy ranging 80-99% is achieved. The model is used to predict the maximum internal corrosion rate of PHE ONWJ’s pipeline and become a basis in determining pipeline’s integrity status, remaining life and assisted in assessing the pipeline risk. Those outcome are then become an action plan. Therefore, a joint study is made to create such corrosion model for pipelines. The goal is to have an in-depth approach in managing matured and unpigable pipeline integrity that can be effectively operated gobally and to ensure all stakeholders that it is safe to operate the pipeline.

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.

Complete Integrity Assessment of a Non-Piggable Multi-Diameter Cross Country Pipeline in a Network Shared by Multiple Electrically Continuous Parallel Pipelines

2021 ◽  
Author(s):  
Amit Mishra ◽  
Saurabh Vats ◽  
Carlos A. Palacios T. ◽  
Himanshu Joshi ◽  
Ishan Khurana
Keyword(s):  
Stress Corrosion ◽  
Stress Corrosion Cracking ◽  
Accurate Data ◽  
Internal Corrosion ◽  
Integrity Assessment ◽  
Direct Assessment ◽  
Integrity Management ◽  
The Subject ◽  
Cross Country ◽  
External Corrosion

Abstract A complete Pipeline Integrity Management System is the need of the hour. Apart from keeping in mind the enormous environment concerns in this rapidly dwindling era of hydrocarbons, a successful pipeline owner always strives to profitably operate their precious assets. To operate a pipeline efficiently, a plan is required to maintain its health and increase the remaining life. Various types of pipelines pose various problems which the owner needs to resolve systematically and with a well-ordered approach. A similar challenge was faced by a refinery in India. The refinery has a design capacity to process 15 MMTPA of crude per annum. The imports and exports are carried out through the local Port Trust which is one of the deepest inner harbour on the west coast. Multiple pipelines run to and from the refinery and the port trust (approximate distance — 10 km). The subject pipeline in question currently transports Mixed Xylene (MX) from refinery to port. The pipeline has a diversified operating history with various other products being transferred in the past. However, the pipeline is used very scarcely. The problem posed by the subject pipeline was similar to what many other cross-country pipelines face — the pipeline was not piggable. Five (5) other parallel pipelines share the same right-of-way, all of which are piggable and have their integrity assessment performed via Intelligent Pigging on a planned basis. There was also a concern about collecting the most accurate data since the pipeline had not undergone an integrity assessment since its commissioning in 2001. However, it was yearly pressure tested to ensure integrity of the pipeline. Parallel pipelines pose a bigger challenge for obtaining accurate data for a particular pipeline amongst them. Keeping all this in mind, a complete integrity management was planned for the MX pipeline and thus concluded on performing a turnkey Direct Assessment (DA) program. The DA program included Internal Corrosion Direct Assessment (ICDA) to assess and manage the threats of internal corrosion, External Corrosion Direct Assessment (ECDA) for external corrosion threats and Stress Corrosion Cracking Direct Assessment (SCCDA) for determining susceptibility towards the threat of stress corrosion cracking on the pipeline. Utilization of latest technologies helped in adapting and overcoming the multiple problems faced by legacy technologies especially in difficult ROW conditions and complex pipeline networks, such as the MX pipeline. This paper provides an insight into how an operator can combine latest available technologies and deploy it in unison with the complete integrity management plan.

Piping Corrosion Rate and Remaining Life Basis: Commercializing Conservatism in First Time Inspections

2014 ◽  
Author(s):  
Graig Cilluffo
Keyword(s):  
Corrosion Rate ◽  
Nuclear Power ◽  
Corrosion Monitoring ◽  
Internal Corrosion ◽  
Novel Approach ◽  
Piping Systems ◽  
Plant Data ◽  
Inspection Data ◽  
Plant Inspection ◽  
First Time

This paper sets forth guidance on how to establish a justifiable internal corrosion rate following a first time inspection to predict re-inspection or replacement timing for raw water piping. A novel approach leverages actual plant-wide piping inspection data, leak history, repair history, and corrosion monitoring results together to inform integrity decisions based on experience at a reliably-operating, nuclear power plant. Data is applied on a risk-conscious basis to piping systems based upon failure consequence and uncertainty and differs from the typical approach of reporting location-specific, time-averaged rates. Excavation and in-plant inspection results can now inform commercially-friendly conservatism that reduces leak risks while also minimizing total inspection and maintenance costs. While directly applicable to buried piping, this method can be applied to any corrosive system / location. Information is presented in a format that readers can readily follow to develop similar justifications for their own sites / systems. Guidance on applications, limitations, and areas for improvement are also provided.

Potential Components of an Effective LSW Integrity Management Program

2012 ◽  
Author(s):  
Tara Podnar ◽  
Thomas A. Bubenik ◽  
Jim Andrew ◽  
Dyke Hicks
Keyword(s):  
Positive Impact ◽  
Management Program ◽  
Safety Measures ◽  
Integrity Assessment ◽  
Seam Weld ◽  
Integrity Management ◽  
Examination Techniques ◽  
Inspection Data ◽  
Non Destructive ◽  
Longitudinal Seam

Det Norske Veritas (U.S.A.), Inc. (DNV) has had the opportunity to observe and contribute to a significant number of longitudinal seam weld integrity management programs. DNV has used these opportunities to identify activities with a positive impact on the integrity management of the longitudinal seam welds for which they are implemented. The Integrity Assessment activities identified by DNV include those pertaining to hydrostatic pressure testing, in-line inspection data, and in-line inspection technology. The Anomaly Review and Prioritization activities include excavation prioritization, control excavations, and investigative excavations. The Excavation and Repair Program activities include non-destructive examination techniques, technologies and validation, repair methods, and safety measures. The Tool Validation activities include in-line inspection specification and vendor feedback. The Reassessment activities include those pertaining to in-line inspection validation, operations, and reassessment interval calculation methodologies. Not all longitudinal seam weld integrity management activities are appropriate for all pipelines. In these cases, the correct combination of integrity management activities will result in an effective longitudinal seam weld integrity management program.

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