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2019 API Inspection and Mechanical Integrity Summit

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When: January 28, 2019 - January 31, 2019

Where: Galveston Island Convention Center, Galveston, Texas

Open for Registration Details

Asset Integrity Through Corrosion Management, Inspection, and Engineering Technology


NEW KEYNOTE SPEAKER ANNOUNCED: John Reynolds, MDC, Principal Consultant, Intertek Asset Integrity Management, Inc.

Preliminary Program - Available Soon

Panel Descriptions - Available Soon

The API Summit was designed with you in mind. This four-day summit includes three days of presentations spanning over 120 topics. Addressing issues involved in asset condition evaluation for drilling, production systems, pipelines, terminals, refining, chemical manufacturing and storage facilities. In addition, an optional day of  training is conducted by subject matter experts. Each day focuses on presentations relevant to upstream, midstream, downstream operation and integrity management. API Inspection Summit provides an opportunity to learn about new and existing industry codes and standards, to hear about emerging trends from experts, and to discuss new and existing issues in inspection and AIM technology. 

The API Summit is the only networking event for inspectors and other inspection support professionals in the industry. As stated by attendees, “The API Summit is the best inspection related conference in the petroleum industry”.

The following oil, gas and chemical sectors will be covered:

  • Upstream (Drilling, Sub Sea, Production Systems, Integrity Management)
  • Midstream (Pipelines, Terminals)
  • Downstream (Refining, Chemical & Storage)

Monday, January 28 will be dedicated to Training Courses run by Subject Matter Experts.

Three primary topics – Inspection/NDE, Metallurgy/Corrosion, Engineering & Analysis (tracks) will run concurrently each day (Tuesday, Wednesday and Thursday).  

Schedule at a Glance 

January 28 January 29, 30, & 31


Training Courses




Exhibition
Inspection / NDE Track
Metallurgy / Corrosion Track
Engineering & Analysis Track

Media Sponsors

Inspectioneering  

Questions?

Email: inspectionsummit@api.org or Call: 202-682-8195

Selected Presentation Abstracts can be viewed below

8:00 A.M. – 5:00 P.M.

8 Hour Courses

RBI


Instructor: Lynne Kaley, P.E., Principal, Trinity Bridge, LLC;

The details of API’s recommended practices (API 580 Third Edition and API 581 Third Edition) will be presented by recognized industry experts and leaders in the development and use of RBI methodology. API RP 580 introduces the principles and presents minimum general guidelines for developing a RBI program for fixed equipment and piping. API 581 provides quantitative RBI methods to establish an inspection program. Together, these two documents comprise a widely-recognized standard for industry-accepted RBI practices. Both of these recommended practices were updated, and new editions released in 2015. The course helps attendees understand and use RBI technology, develop a program, and learn which RBI procedures and working processes comply with industry standards. Additionally, changes between the Second and Third Editions will be highlighted and discussed.

FFS


Instructor: David Osage, ASME Fellow, PE, The Equity Engineering Group

This one-day course provides the inspector or engineer with an in-depth overview of the Fitness-For-Service (FFS) Assessment Methods in API 579-1/ASME FFS-1, 2016 Edition. The course includes a segment describing how the document is organized, insights on how to navigate through the document to apply FFS technology (i.e. either reactive or proactive), and a review of the three FFS assessment levels and what constitutes a “best-buy,” how do decide on which level to use based on the damage mechanism and NDE information provided. An overview of the Life Cycle Management process for fixed equipment is also provided explaining the interactions between the AMSE and API construction codes, API Inspection codes, and API 579-1/ASME FFS-1. All FFS assessment methods will be discussed with an emphasis on the volumetric damage assessment methods for general and local metal loss and pitting, HIC./SOHIC and hydrogen blisters, crack-like flaw assessment methods and remaining life estimation for high temperature components including an overview of MPC Project Omega. Attendees are encouraged to bring current problems to the class for discussion. The notes provided for the course will cover all Parts of API 579-1/ASME FFS-1, 2016 Edition, and are provided to the students for general Information.

Design, Inspection and Assessment of Aboveground Storage Tanks


Instructor: Joel Andreani, P.E., Principal Engineer, The Equity Engineering Group, Inc.

This session will cover: API 620, 650 and Series 12 Storage Tank Designs – What’s required in the main standards; Other Best Practices. In-Service Inspection of Storage Tanks – API 653 Inspections; Tank RBI in API 653; Other Best Practices. Assessment of Existing Storage Tanks – API 653 Assessments; API 579 Techniques applicable to Tanks; Settlement/Foundation Assessments; Other Tank Mechanical Integrity Best Practices.

Recent Modifications to the API Standards for Design, Installation and Inspection of Pressure Relief Devices


Instructor: Phil Henry, Principal Engineer, Equity Engineering

This class will cover: API Pressure Relief Document Overview – API 520 Overview – Basic Terminology; PRV Design and Operation; Sizing and Selection; Installation Requirements. API 521 Overview – Design Philosophy; Overpressure Scenarios. API 576 Inspection of Pressure Relief Devices – RBI for PRDs per API 521; Inlet Pressure Drop-3% rule; Tube Rupture Scenario; What’s coming in API PRS Standards.

Fired Heater Integrity Optimization Management


Instructor: Tim Hill, Process Engineering Optimization Manager, Quest Integrity USA, LLC

This course is designed for engineers, operators, maintenance, inspectors, safety, and training personnel working with or responsible for integrity issues associated with fired heaters. Fired Heater Integrity Optimization Management helps attendees learn the science of optimizing reliability and performance factors that affect tube integrity management of fired heaters and reformers. This course applies the essential theories, such as IOW, RBI, etc., provided in API Standards and Recommended Practices and practical approaches to fired heater monitoring to evaluate operating risk, damage mechanisms, failure analysis, safety, fitness-for-service and remaining life of critical components. Learn the necessary elements to inspect and maintain fired heaters using best practices that minimize risk, minimize the amount of shutdown work and maximize performance.

Guided Wave Testing of Pipeline, Pressure Vessel, and Tanks


Instructor: Sang Kim, Ph.D., CEO, Guided Wave Analysis, LLC

API RP 583 included guided wave testing (GWT) as a screening method to identify potential areas of CUI damage on piping in 2014. After that, this guided wave testing (GWT) method has been much improved in spatial resolution and sensitivity. GWT method can examine accumulated pitting corrosion of less than 1 % of the pipe cross sectional area and detect 0.3 inch by 0.3inch and half-wall localized defect at 10-ft distance in any diameter of pipe, pressure vessels, and tanks. This course will present basic knowledge of guided wave testing, sensitivity of guided wave testing, spatial resolution, selection of operating center frequency, inspection range, inspection report, high-temperature pipeline testing, CUI and PMI application, and field testing examples of piping, pressure vessels, and tanks. Reports generated with many field testings are presented for showing capabilities and limitations of GWT method. During the course, the GWT method will be demonstrated with sample pipe and plate structure having defects. It is designed for API inspectors, maintenance management personnel, operators responsible for piping, pressure vessels, and tank in oil or gas companies, refinery, chemical, and petrochemical plants. Participants will gain an understanding of ultrasonic guided wave testing method for inspecting piping, pressure vessel, and tank.

Damage Mechanisms Affecting Equipment In the Refining and Petrochemical Industries


Instructor: Isaac Pabon, Materials Engineer, ExxonMobil, Deric Masten, Welding Engineer, Motiva, Carlos Palacios, Ph.D., Upstream Specialist, CIMA-TQ, Tom Pickthall, Jr., Pipeline Specialist, EnhanceCo, Marc McConnell, Corrosion Engineer, Pro-Surve

This class will provide a general background on the material contained in API 571 (Damage Mechanisms Affecting Fixed Equipment in the Refining and Petrochemical Industries). Everyone in the refining industry today, including the refinery owner, refinery operator, mechanical engineer, metallurgist, and process engineer, is looking for ways to prevent or minimize the effects of corrosion. Corrosion control is paramount to the safe and productive operation of a facility. As we all know, a key first step in safety and reliability of our mechanical equipment is the identification and understanding of the relevant damage mechanisms. Proper identification of damage mechanisms is important when: Implementing the API Inspection Codes (510, 570 & 653), conducting risk-based inspection per API 580, and performing a fitness-for-service assessment using API 579. Damage mechanisms need to be understood and considered to determine corrosion rate, location (general or local) and opportunities for mitigation. We will start the day with basics of corrosion and work our way into the most common details of causing corrosion. Audience participation will be greatly encouraged. Those attending are welcome to bring Power Point slides of opportunities and have the class comment on them.

Hydroprocessing Inspector Training


Instructors: Scott McArthur, P66 and Brian Jack

The Hydroprocessing Inspector Training is designed to provide a more in depth understanding on the operations, the basic corrosion / damage mechanisms and inspection considerations specifically found in hydroprcessing units (hydrocrackers and hydrodesulfurization units). This training approach, focusing on the process unit, differs from the typical API 571 (Damage Mechanism) course by providing a wholistic view of unit operation and targeting the specific problems areas for inspection and process monitoring. A fundamental understanding on the operation basics and process control with the resulting damage mechanisms provides a better foundation for establishing a comprehensive mechanical integrity program. This 8 hour training course will cover three key aspects of hydroprocessing as follows; Unit Operation – taught by a Corporate Process Engineering Lead (Scott McArthur – P66) covering the background on unit operation, process variables and control, including basic reactions and potentially corrosive byproduct produced in typical hydrotreating and hydroprocessing units; Damage Mechanisms and Inspection – taught by a Corrosion / Materials Engineer (Brian Jack – former Chief Engineer at P66) covering the different key damage mechanisms that can occur in hydroprocessing, including the typical locations of concern, process variable monitoring (Integrity Operating Windows) and inspection techniques.

8:00 A.M. – 12:00 P.M.

A.M. 4 Hour Courses

CCDs/API 970/API 584


Instructor: Gerrit Buchheim, Refining Metallurgical and Corrosion Expert, Becht Engineering Co., Inc. and Matt Caserta, Mechanical Integrity and Inspection Expert, Becht Engineering Co., Inc

This training course will introduce the attendees to the concepts of Corrosion Control Documents (CCDs) and Integrity Operating Windows (IOWs). This course will review the recommendations and requirements within each API recommended practice for both topics, API 970 for CCDs and API 584 for IOWs, as well as the interaction between the two programs. Additionally, the course will cover how to implement a CCD/IOW program including: resources, team members, process information, inspection highlights, CML data, and among others. Finally, example CCDs and IOWs will be reviewed.

Introduction to Metallurgy for the Inspector or Reliability Equipment Engineer


Instructor: Jeremy Staats, P.E., Becht, Jeremy Nelson, P.E. Flint Hills Resources, Dave Moore, Becht Engineering Co., Inc.

This 4-hour course provides the inspector or fixed equipment/ reliability engineer with an introduction to basic concepts of metallurgy. The course will start with metal processing and forming, go through the various alloys of construction in refining and petrochemical plants, and touch on various aspects of through heat treating and welding. As certain metallurgical concepts are discussed, related damage mechanisms, inspection techniques, and reliability strategies will be covered.

Bolted Flange Joint Inspection Training


Instructor: Scott Hamilton, Founder and CEO, Hex Technology

Hex Technology trains individuals on the design and importance of each individual part of the BFJA (academic training). This will cover: Introduction to ASME PCC-1; Introduction to “Appendix-O” of PCC-1 and Limiting Factors; Joint cleaning for inspection requirements; Inspection and mitigation for flange/nut contact region; Inspection for gasket seating surface finish; Inspection for gasket seating surface imperfections; Inspection for gasket seating surface flatness; For both raised face and RTJ; In-Service inspection criteria; Setting manual & “Powered Equipment” wrenches.

Characteristics of the High Performing Inspector


Instructor: Mark Smith, MSTS-Training

Most inspectors are on jobs that present significant challenges. Technical situations, relationships with other plant departments, and high workloads are just some of the common challenges facing today’s inspectors. Sometimes, technically qualified inspectors, still underperform in their work assignments. Why? Often it is because of their limited abilities in important non-technical skills. This training session will help inspection personnel see a broad picture of the make-up of a High-Performing Inspector. Key focus in this training session will be the non-technical skills and character qualities that set apart the High Performing Inspectors. Throughout this session there will be plenty of “real-world” illustrations of individuals demonstrating the Key Points! Major points in the discussion include: Keep developing new talents – both technical and non-technical skills (writing, organizing, persuasive communication, directing others, etc.). Many inspectors run from important issues like corrosion mechanisms. The most successful will “run toward their fears”; Go the “Extra Mile” – do more than expected; Get excited about making others successful; Avoid organizational killers - no whining, no back stabbing, etc.

1:00 P.M. – 5:00 P.M.

P.M. 4 Hour Courses

Bolted Flange Joint Assembly


Instructor: Scott Hamilton, Founder and CEO, Hex Technology

The Bolted Flange Joint Assembly (BFJA) has several critical pieces that need to be inspected during assembly. Some of these items include: bolts, nuts, flange surfaces, gasket sealing surfaces, and setting of torque wrenches. In order to understand what to inspect, it is imperative to understand why those items are important to the overall BFJA.

Overview of ASME PCC-2 through Case Studies


Instructor: George Antaki, PE, Fellow ASME, Becht Engineering Company

A four-hour overview of vessels, piping, and tank repair options addressed in PCC-2, through case studies. Each repair technique will include lessons learned, dos-and-don’ts, and similarities and differences in implementation among industries. The repair options are subdivided into welded repairs, mechanical repairs, and non-metallic wrap repairs. For each repair, the overview will provide a practical checklist of the design, implementation, NDE, and leak testing considerations.

An Overview for Owner User Inspectors/Engineers to Develop and Execute Turnaround Inspection Plans per Industry Best Practice Expectations


Instructor: John Conway, Inspection Planning Division Manager, Becht Engineering

This 4 hour seminar will define key deliverables necessary to support the following four phase Inspection Planning Process; Scoping; Planning; Execution; Evergreening. The training will focus on: Defining the Inspection Planner roles and responsibilities and skillsets necessary to support a facilities Turnaround Planning Program to execute a Best Practice Turnaround effort. Key topics to be discussed include; Validate Risk Based Inspection Plan complies with regulatory compliance; Mitigate inspection discovery (“no surprises”); Facilitate Risk Based Work Selection Process; Optimize planning and prioritize planned work; Develop detailed work execution packages with planners and schedulers; Mitigate critical path impacts during execution; Evergreen inspection plan for next turnaround.

The Inspector Writes – Technical Writing for Inspectors


Instructor: Mark Smith, MSTS-Training

This presentation will: Emphasize the importance of good writing skills for individuals in the pressure equipment discipline; Provide a brief overview of the importance and use of inspection narratives; Provide simple writing rules that are useful when performing technical writing, i.e. inspection narratives; Encourage listeners that technical writing skills are a learnable skill! It is not just for those with “natural abilities”!

Enhanced RBI for exchanger bundles


Ricardo Gonzalez, Total SA

The application of RBI for exchanger bundles presents several challenges. Approaches that address business interruption are often too conservative and expensive to implement. Inspecting thousands of tubes is too expensive and not practical, but smaller samples do not always accurately represent the rest of the bundle. TOTAL R C presents a method that was developed based on the API 581 method and enhanced using statistical treatment of the NDT data through Extreme Value Analysis. This enhanced model allowed us to optimize the scope of NDT during turnarounds, improve process availability, and refine our response to process-related corrosion issues. The approach was applied to more than 1600 bundles by 2016 and is now standard practice.

Risk-based inspection applied to Russian refineries


Karina Allogulova ,ZAO “GIAP-DIST Center”

Russian regulations require shutdown, inspection and repair of refinery equipment at specific intervals. Recently, they have permitted extension to the run-time based on an accepted probability ranking of assets. The presentation will: Overview the usage of the risk-based approaches applied to assets within Russian oil refineries; Specify the difficulties faced by users during the implementation; Demonstrate the gradation of assets according to the degree of risk. This system led to the optimization of the inspection program by defining efficient resource allocation including the methods assigned, the volume and frequency of the inspection been implemented. Show the methodology approved by the Russian Federation to increase time between shutdowns.

How Risk-Based Inspection Ruined My Life


Brent Ray, Marathon Petroleum Corporation

In this crazy world we live in, someone or some group of people decided that statistics could actually predict - within reason - when a piece of equipment would fail. However, this doesn't account for the spontaneity of the universe in popping the cork a bit too soon. Nor does it account for the mistakes that human beings are so prone to make. It has been an extremely painful pleasure to work with risk-based inspection and its methodology over the years, but sometimes we take it a little too seriously. This presentation will try to be lighthearted and provide examples of where RBI can be difficult to manage or implement, including ruining my life at times.

RBI model for creep based on Larson Miller parameters


Panos Topalis, DNV GL

A new model for the calculation of the probability of failure (PoF) of furnace tubes and boiler components from creep has been developed. The long-term creep model uses Larson Miller parameters from the industry standard API RP 530. A limit state function involving creep remaining life is defined and PoF is calculated through integration based on the mean value first order second moment (MVFOSM) approximation. The effect of variability of creep stress and temperature on the PoF is investigated. The PoF calculation can also take into account metallurgical replication results. The model is currently considered for a ballot for the next edition of API RP 581

Case Study: Qualitative Risk Assessment of a Refrigeration System


Robert Sladek, Asset Optimization Consultants

This case study will present the methods that were used to calculate qualitative risk for a critical refrigeration system and the results of the assessment. This case study is intended to demonstrate how a Qualitative Risk Assessment can be a cost-effective and resource-efficient means to prioritize equipment often under the radar.

This assessment was performed to scope a capital, reliability investment by focusing the inspections, improvements and repairs to ensure reliable future operation. Probability was assessed using simple hoop stress, historical and expected corrosion rates and also accounted for unique damage mechanisms. Consequence was tabulated on Safety, Environmental and Operational factors based on Site SME review and assignment. A non-standard risk matrix was developed based on the needs of the site.

Case Study: Steam System Risk Mitigation using RBI


Robert Sladek, Asset Optimization Consultants

This unit had undergone many upgrades over its 60 years of operation. The unintended consequences of these "upgrades" revealed many issues, some which threatened shutdown. Risk Based Inspection was used to prioritize steam, condensate and BFW piping in this aged unit. This project resulted in inspection and maintenance mitigation recommendations prioritized based upon risk. The presentation will cover the project scope, required inputs, mitigation recommendations and the prioritized mitigation implementation methodology.

Objective Comparison of Two RBI Methodologies and Results


Clay White, Phillips 66

This presentation covers the comparison of two different commercially available RBI analysis methods applied to a Refinery Crude and Hydroprocessing Units. To the degree possible, data and program settings were identical to produce a reasonable comparison of the results. This presentation focuses on the key differences between the analysis results obtained and objectively identifies the technical calculation / approach differences that resulted in the likelihood, consequence and risk of failure with corresponding inspection recommendations.

How People, Processes and Technology provide RBI Program Success


Bastian Zars, Lloyds Register Energy Canada Limited

Why should you adopt a Risk Based Inspection (RBI) program? In order to maximize efficiency, it is critical to strike the right balance between safety, risk, cost, and performance. This presentation will provide ideas and further guidance on how to implement a successful RBI program. It is important to understand the three fundamental pillars, which are Process, People, and Technology otherwise known as the Golden Triangle. RBI is both a dynamic and systematic process that helps companies gain valuable knowledge about risk. The program highlights potential blind spots in process units or facilities such as damage mechanisms, risk profiles, and inspection needs. RBI provides a proactive approach to enhance and create a safer, more reliable operation.

Equipment Data Collection for RBI


Tiffani Mickey, The Dow Chemical Company

In recent years, Dow has accelerated our efforts to move from time-based inspection to RBI. One of our biggest challenges with implementation has been the upfront equipment design and operating data collection. Our data primarily resides in scanned PDFs, therefore it is not digitized for manipulation. This presentation will show methods to collect required data and migrate to an RBI software.

Evergreening an RBI-Based Inspection Program


Ben Charlton, Valero Three Rivers

Successful Evergreening of an Inspection Program is critical to assuring asset availability, mechanical integrity and code compliance. Every new asset, repair, process change or excursion must be evaluated to determine its effects on the Mechanical Integrity Program and to ensure that RBI correctly models the damage mechanisms that may be present. Processes and procedures that reliably provide consistent Evergreening results must be in place and staff must be dedicated to the Evergreening process. This presentation will describe an owner-user’s Evergreening process to maintain data as current and valid to support the mechanical integrity program and assist in planning turnarounds, repairs, replacements and upgrades.

Risk-Based Inspection Methodology for Bundles, Tanks and Furnace Tubes


Lynne Kaley, Trinity Bridge, LLC

Risk-Based Inspection (RBI) is accepted and has been widely used to optimize inspection activities in the industry starting in the 1990’s. While RBI for pressure vessels has been generally accepted and managed, special equipment using risk-based practices have been more challenging. The presentation will outline approaches for application to heat exchanger bundles, storage tanks and fired heater tubes being discussed and tested in the API RP 581 committee. Examples of risk results and recommended inspection and/or replacement will be included to demonstrate the approach.

Owner User Modification of API-581 Levels of Inspection Effectiveness Procedures


Mark Vining, MISTRAS Group

The intent is to clarify that Owner User interpretation of Part 2, Annex 2.C of the API 581 base resource document (BRD) can justify the modification of the Levels of Inspection Effectiveness (LoIE) procedures used to plan and document a risk based inspection program. Additional value is derived from improved application of inspection techniques based on more appropriate inspection related activities designed specifically for the organization by internal and external subject matter experts (SMEs). Modification of the procedures can generate exceptional value when performed in collaboration with individuals trained in the generation and execution of professionally developed procedures. The Owner User/SME collaboration aids in the reduction of a facility risk profile through the creation and utilization of professionally engineered and customized risk based inspection plans.

Non-Intrusive NDT and Customized RBI Solutions


Siddarth Sanghavi, PinnacleART

With the recent downfall in oil prices, it is becoming increasingly difficult to optimize operating costs while efficiently maintaining asset integrity, managing risk, and safely meeting production targets. A customized semi-quantitative RBI program with a proactive approach to addressing asset risk by utilizing API 580 and 581 recommended practices along with emphasis placed on utilizing on-stream inspection techniques can help support production goals, minimize equipment downtime while maintaining mechanical integrity of assets and mitigating any HSE risks. Performing such a RBI analysis for an upstream processing facility resulted in an increase of long-term availability of the facility, and in turn, will provide increased production revenue of $16 million USD for next 5 years.

Benefits & Limitations of using RBI on ASTs


John Britton, DNV GL

The presentation will detail the benefits as well as limitations for implementing risk based inspection (RBI) on above ground storage tanks (ASTs) using API 581 methodology. The presentation will highlight the differences between AST RBI and Vessel / piping RBI including differing input variables and output calculations. During the presentation a comparison between API 653 section 6 condition/time based versus risk based will be discussed. To show the potential benefits of performing RBI on ASTs, the presentation will also show the highlights of a case study for over 100 ASTs at a single refining facility.

Interaction of RBI, IOWs and CCDs in mechanical integrity programs


Juergen Deininger, TUEV SUED Industry Service GmbH

An important step in RBI is the definition of corrosion loops within a plant, as it serves as a basis for the subsequent analysis for probability of failure. Proper documentation can be done in Corrosion Control Documents (CCDs), containing critical factors, corrosion history, etc. The document can serve the asset engineer as a helping tool for MOC meetings and helps to keep corrosion knowledge and history within the organization when employees leave the organization. The gained knowledge can be used for the definition of Integrity Operating Windows (IOWs) with measurement frequencies, predefined actions etc. The list of IOWs is also documented in the Corrosion Control Documents. Excursions from IOWs can be used for inspection planning and evergreening of RBI or RBI-reassessments.

Can you Manage RBI Records real-time during a Turnaround? Absolutely!


Marc McConnell, Pro-Surve Technical Services

So you implemented RBI, let's take it to the next level. Lets go for real-time RBI turnaround management. This presentation will present a case study of our goal to update records in real time during the execution of a major turnaround. We will present some of the challenges that occurred, our solutions to those challenges, and of course a comparison of expected management results versus actual results. If you have ever been working on turnaround paperwork months after execution or thought that getting all your turnaround data updated during execution would be too daunting, cost prohibitive, and downright impossible; this session is for you.

Using Actual Pop Test results to determine PRD Risk


Hassan Sadeghi, Lloyd's Register

Traditional API 581 risk approach can have mixed results for establishing PRVs inspection interval. Probability of Failure (PoF) is low for most cases therefore Consequence of Failure (CoF) drives risk, leading to impractical inspection frequencies. This coerces the engineering teams to evaluate other more realistic inspection intervals for cost/safety reasons either based on experience or industry data rather than asset information. An alternative adaptive methodology is discussed in this presentation where PoF and CoF are based on user defined Risk Reduction Targets and Safety Integrity Levels. This methodology captures how using actual in-service testing results rather than default values can deliver a more representative PoF and how it can be reliably used to deliver an optimum test frequency based on quantitative assessment of failure modes.

Fired Heater Risk-Based Inspection Methodology


Phil Henry, The Equity Engineering Group, Inc.

In addition to the risks of tube rupture, fired heaters have a significant additional risk of explosions due to poor combustion management. An RBI program that includes fixed equipment (vessels, piping, exchangers, etc.) without addressing the unique risks associated with fired heater operation ignores one of the major sources of risk on an operating unit. The presentation will provide a method for performing risk-based inspection and risk mitigation of fired heaters that fits well within the structure of an API 581 based RBI program. The method provides state of the art probabilistic models for combined creep and thinning damage for predicting Probability of Failure (POF) of heater tubes. Case studies will be provided with real world fired heater data from Owner/Users

Qualitative RBI Approach For Heat Exchanger Damages Mitigation


Ahmad Raza Khan Rana, Dalhousie University Halifax NS - Canada

Heat exchangers with welded channel heads and helical twisted tapes inside tubes (called spiro-vanes) pose great inspection and repair challenges. Such heat exchangers are common in cryogenic process applications. In the absence of sound RBI implementation in inspection plans, certain damage mechanisms and failure modes could remain un-addressed leading to catastrophic failure of the heat exchangers. This presentation highlights a case study of different damage mechanisms (cold weld cracking, cooling water corrosion etc.) that caused permanent failure of a cryogenic heat exchanger. This presentation details a simplified and cost-effective RBI strategy to mitigate various risks associated with such heat exchangers. Finally, it provides guidelines to various stakeholders (Inspectors, Engineers and managers etc.) to assist with decision making even in the absence of quantified data.

Proactive Design Criterion to Maximize Integrity of Facility Assets


Mohamed Attia Ahmed, Saudi Aramco

In-service inspection is a key element in assuring the integrity of oil and gas facilities. Current Inspection techniques can be highly effective in determining the asset integrity, provided that the component is designed for inspection. However, the deployment of on-stream inspection are largely affected by the equipment configuration and accessibility provisions inherited from the design phase. In addition, absence of fabrication data increases the difficulty in segregating between manufacture/construction defects. This paper present front-loading the inspectability and testability factors that need to be considered in the design of any O&G asset. This has been done by drawing from lessons learned of plant operation and inspection to compile a guidance that should be attained when designing a plant assetto ensure practicality of performing on-stream inspections.

Aging Asset Optimisation


Hossam Aboegla, Llyod's Register Energy

The emerging demands for managing aging issues and life-extension requirements to ensure sustainable and safe operation, should be evolved into a holistic framework of asset integrity management strategy (AIMS). Poor management of aging assets challenge any requirements for effective assessment or decision making. Hence, exsiting uncertainties may result in unforeseen future costs andcatastrophic failures. The framework eliminated traditional silos of asset management between topside, pipeline and subsea facilities. Therefore, a holistic approach in developing consistent and integrated AMS, was a necessity to manage different components in a standardized way. Net reduction in maintenance budget by 40%. Managment ofaging risks andlife-extensiondemands up to +15 years beyond design life. Updatesin CAPEX plansby 90%.

Monitoring of structural integrity of offshore structures in cold regions


Arpit Dev, OMCI Rig Technical and support services

It has been well established that concrete structures are the most reliable, efficient and cost effective solution for drilling for oil or gas in the colder regions. To make the structure as a cost effective one requires enhancement in its operational life.There are not many proposals or models for structural integrity management for colder regions drilling as the fields are new and most are still some way before full-scale operations start. In this paper we shall be looking into various means and new methodologies to track/monitor ice pack advances and creating models for inspection-eering and studying/analysing structural integrity of these structures.

Offshore casing conductor splash zone repair alternatives


Chanat Sirisoonthorn, Chevron Thailand Exploration and Production, Ltd.

"Preventing chance of oil spill, the leakage on surface casing from marine atmospheric corrosionismanipulatedby premature well plug and abandonmentdue to the difficulty of repairingespecially onthesplash zone. This study covered the alternatives of prolonging lifetime on surface casingat splash zoneto enhance well integrity instead of abandonment. The studied alternatives include sealing cl, cl with compound injection, epoxy sleeve and full encirclement sleeve (with underwater welding operation). Theserepairingmethods'efficiency and limitation are considered based on the repairfeasibility, design life, safety, economic justification and removal difficulty. The audience working in upstream and coping with well integrity management will acknowledge about individual pros and cons and be able to apply with other condition and field of work."

CML Optimization / Allocation


Grady Hatton, Pro-Surve Technical Services, LLC.

CML optimization and allocation continues to be a large part of the industries reliability programs. Whether it is a new expansion or aging facility, the placement of CML’s can be a major factor in the inspection budget. Gaining confidence that the CML is giving the most for the money spent is of paramount importance. Understanding how palcement of the CML adds quality to the inspection dataand thereby allows for accurate corrosion forcasting. The main objective of the presentation will be to discuss the need for damage mechanism studies, inspector experience, IOW's, and the utilization of existing knowledge and science to better understand the placement of CML's and formulate mechanical integrity test plans. Defining your scope where CML's are concerned should be clear and precise.

Erosion and Sand Management in the Unconventional Business


Juan Gonzalez, Shell Upstream Americas Unconventionals

The risk of LOPC’s related to sand/erosion has become an important work item for everyone in the Shale Business since it poses a large HSEE risk, and economic impact. This presentation captures experiences, as well as industry standards; providing best practices for erosion control and mitigation of wells and facilities in shale gas/oil service supporting hydraulically fractured wells. Erosion control methods are continually evolving to remove conservatism and extend the operating boundaries for producing wells in both cleanup flowback operations and to permanent facilities; it is necessary to define proper risk assessment, design parameters, operational control and erosion monitoring to mitigate erosion due to frac sand, and high velocities/jetting. It includes recommendations for: Facility Design, Well Integrity, and Producing Operations & Surveillance are presented.

Can We Learn from Manufacturing? A Case for Quality Improvement


Joey Poret, Chevron Corporation

The manufacturing industry has developed and implemented a framework for quality improvement for almost 50 years now, beginning with the work of W. E. Deming in Japan through the implementation of Lean Six Sigma and Total Quality Management. The results, if to be believed, are impressive, so why hasn't the Oil and Gas sector fully embraced this transformational culture? This presentation will discuss the roadblocks to quality improvement implementation in the upstream sector and provide real-world exles of where these projects have succeeded and failed.

Assessing Performance of a Corrosion Control Program & Data Analytics


Jamie Davidson, Lloyd's Register Energy Americas Inc.

To further optimize Asset Integrity Management (AIM) programs both the inspection and corrosion control programs should be interactiveandproactive. This will move programs away from high OPEX costs and volumes of inspection searching forcorroded equipment and towards management of fluidcorrosion properties. This presentation will cover a real-life exle looking at the corrosion profile of a production process train on an upstream facility. By assessing the data collected and understanding the actual corrosion properties of the process both through data trending and visualization, the effectiveness of the corrosion control program can be evaluated with recommendations to further improve it.This assessment also includes aneconomic assessment looking at the associated costs for maintaining or improving a CCP against losses fordowntime repairing equipment.

Assessing Performance of a Corrosion Control Program & Data Analytics


Jamie Davidson, Lloyd's Register Energy Americas Inc.

To further optimize Asset Integrity Management (AIM) programs both the inspection and corrosion control programs should be interactiveandproactive. This will move programs away from high OPEX costs and volumes of inspection searching forcorroded equipment and towards management of fluidcorrosion properties. This presentation will cover a real-life exle looking at the corrosion profile of a production process train on an upstream facility. By assessing the data collected and understanding the actual corrosion properties of the process both through data trending and visualization, the effectiveness of the corrosion control program can be evaluated with recommendations to further improve it.This assessment also includes aneconomic assessment looking at the associated costs for maintaining or improving a CCP against losses fordowntime repairing equipment.

Field Evaluation of Eddy Current Probe


David Brown, Vir Systems

This presentation discusses independent field validations of our T5 Array eddy current probe in various types of heat exchanger tubing. The T5 consists of a series of coils arrayed for 100% circumferential coverage and attached together to operate from a single differential bridge channel on a common Eddy Current instrument. The array is optimized for detection of axial and circumferential cracking while minimizing signals from tube supports, tube sheets, lands, fins and internal enhancements. These coils do not provide optimal detection or sizing for volumetric flaws, and are usually paired with a conventional differential bobbin coil set as a supplement. Operation of the probe will be described and the advantages and limitations of the probe technology as shown in a variety of field applications.

Maintaining Aging Infrastructures in Upsream Operations - A Continuum of Approaches


Travis Harrington, Anadarko

"Upstream Operations normally involve assets that are exposed to harsh marine environments for most of their asset life. To maintain these structures and their supporting infrastructure is a continuous and focused effort of prevention over the course of their lifecycle. This presentation will cover some of the more critical maintenance and Integrity topics and approaches. The presentation will begin with early life cycle and will continue thru to decommissioning to show the varying approaches and planning that typically takes place."

Verification and Validation of Standard Hammer Union Designs for API Subcommittee 8, Task Group 5


Daniel Ayewah, Stress Engineering Services

Hammer unions have been in widespread use for operations throughout the oil and gas industry without standardization. This raised some concern in the industry due to the safety implications of components with different ratings and tolerances resulting in an assembly with compromised strength. Task Group 5 (TG5) of API Subcommittee 8 is tasked with developing standards for safe hammer union manufacture and operation. Their new standard in progress, will address the issue of hammer union standardization. In this presentation, results of analysis and testing performed as part of the development process for the new designs are presented. The analyses consist initially of performing API 6A design checks, then progresses to more advanced finite element analysis, and finally, testing on a limited set of designs.

Update of API 12 Series Tank Specification and Inspection Documents


George L. Morovich, Tank and Environmental Technologies, Inc.

This presentation will provide an overview of revisions to API 12 Series Storage Tank Specifications (12B, 12D, 12F & 12P), the Facility Set-up, Operation & Inspection Document (12R1) and report on completed API Funded 12F & 12D Research. In response to Owner Operator needs, an objective to increase capacity and working pressure is achieved.

Pipeline Metal Loss Evaluations per API 579-1/ASME FFS-1 Fitness-For-Service Rules


Kraig Shipley, The Equity Engineering Group, Inc.

Analysis procedures from the current edition of API 579-1/ASME FFS-1, “Fitness-For-Service,” applicable to piping systems and pipeline components subjected to local and general metal loss are presented. The applicable sections of the API 579-1/ASME FFS-1 standard will be covered, including evaluation methodologies for local and general metal loss. In this presentation, special attention will be devoted to discussing the applicability, limitations, and common misconceptions of the two thickness averaging procedures (i.e., critical thickness profile approach and point thickness reading approach) documented in Part 4 of API-579/ASME FFS-1 as well as other techniques used in industry (e.g. 3t x 3t technique). Finally a case study is considered in which the procedures discussed herein are used to perform an FFS evaluation of Slug Catcher piping components.

Control Measures During Project for Minimizing Dead Leg in Piping


Brazan Saleh, Kuwait Oil Company

Dead legs are part of piping system that normally have no significant flow/intermittent flow/Stagnant condition which could lead to accelerated localized pitting corrosion resulting in leaks. Describes pipe rupture failure investigation near to a Dead Leg location in one of the KOC facilities and the key findings/recommendations along with the preventive, corrective actions implemented/planned during Project Stage. Effective review of P&ID/Model Review during theFEED /Detailed Design/Construction of facility is of paramount importance in eliminating/minimizing dead legs in facility. Besides the design review, adequate inspection during Construction activities to maintain slope requirement in the piping as required. Also the challenges associated with minimize/eliminating the dead legs of piping, inspection during construction and NDT inspection during in service of the dead leg portion.

Insights from Scale Deployment of Non-Intrusive Inspection Across Upstream assets


George Williamson, BP

Some BP regions have utilized Non-Intrusive Inspection (NII) for pressure vessel integrity endorsements since the mid-1980s. BP has recently deployed a NII strategy to scale across the Upstream asset base. This paper provides insights into program implementation including threat assessment, inspection, metrics, and the overall benefits. The positive impacts include the improvement of operational efficiency, optimizing integrity resource allocations, and the elimination of high risk activities such as opening & blinding, facilities shut-down / start-up and Confined Space Entry (CSE).

A Case Study: Overcoming Integrity Challenges for Tanks/Pipelines.


Mark Slaughter, Intero Integrity

Managing corrosion integrity for tanks andpipelines is challenging.Inspecting tanks floorsnormally require hydrocarbons or chemicalsbeemptied from the tank, creating extra cost and risk to the client. With the use of remotely-operated robotics, many tank floors can now be inspected while they arein-service.The associated piping for transferring the hydrocarbons and chemicals in and out of the storage tanks are an additional integrity risk. The delivery lines are not designed for traditional in-line inspection (ILI) tools. This paper explainshow "Unpiggable" tools and tank floorinspection robotics are designed to overcome thesechallenging inspection operations. Finally, this presentation highlights a case study associated with the inspection of tank farm delivery lines in 2017.

An Inspired Approach to Inspection Methodology for Upstream Production Tanks


Elizabeth Brueckner, G.K. Hills Consulting Ltd.

"Storage tank inspection and reporting requirements are mandated by regulators inCanada. Diversity in characteristics amongst tanks and their systems means various tank installations have different inspection components to ensure integrity and minimize spill events. Tank owners are challenged by inefficient processes and outmoded systems. Following analysis of extensive tank data from varied sources, a mobile application was developed that reduces field time in capturing data while improving its accuracy.Users are only presented with questions relevant to the facility they are examining. Field evaluation showed immediate benefits, providing coverage of 100% of cases with immediate identification of deficiencies previously unobserved, or whose severity had been inappropriately assigned. Resulting dataarchived and integrated with systems in real time, maximizing efficiency and profitability."

New Advances in Contact Point Corrosion Technology


Brian Beresford, VIR Inspection LLC

"This presentation discusses independent laboratory and field validations of VIR wall loss and crack detection and assessment technology for piping between ½” and 20 inches in diameter, corrosion beneath pipe supports, pressure vessels and atmospheric storage tanks. The advantages and limitations of external VIR technology will be shared from blind technology trials from four Offshore and Onshore Owner-Operator companies including NDE validations of minimum remaining wall thickness estimations at various measurement point spacing. An ongoing field trial of VIR permanently installed sensors will also be discussed."

Riser Inspection Internal to J-Tube on a Fixed Leg Platform


Ross Coleman, Shell Oil Company

I will be discussing the unique activities carried out to perform NDE inspections on riser piping internal to a j-tube on an offshore production facility in the Gulf of Mexico. External inspections indicated external corrosion on piping entering a j-tube. A borescope inspection through a gap confirmed corrosion within the j-tube. n order to clean up the area of corrosion and inspect it, windows in the j-tube had to be cut. Due to the j-tube configuration, similar to a pipe-in-pipe with a 3” anulus space in between the j-tube and piping, special tools had to be created to remove the corrosion. A UT probe on a custom rig was created to attach to the j-tube and provide a scan, 360 degrees around the piping.

Advances in Phased Array Inspection of API 620 LNG Tanks


Chris Magruder, Olympus

The increase in LNG tank fabrication projects worldwide combined with the success of portable phased array systems for replacement of radiography has created a demand in the market for off the shelf inspection system solutions that do not disrupt production. Similar to stainless steel weld inspection, the Inconel625 weld is a coarse grained, anisotropic material that requires unique consideration for the phased array probe and wedge designs, and inspection strategy. This paper presents an overview of traditional market solutions for LNG tank inspection using conventional UT and phased array probes, and recent improvements that make replacement of radiography with off the shelf portable phased array systems more accessible in the market. Also included is a live demonstration of LNG weld data analysis and flaw sizing.

Source (3rd Party) Inspection Process Improvement


Joey Poret, Chevron Corp

During the first 3 quarters of 2016, there were a total of 175 third party inspection projects that that cost CTEP almost $200,000 USD and took an average of 6 days to complete (maximum number of days was 77 days). There is an opportunity to improve this process in order to reduce total cost and improving lead time by: Reducing number of inspections by improving the process and capitalizing on the results of the inspections, Increasing the efficiency by removing waste from the process, improve execution of project quality through QA Code assignments

Advances in PIpeline Leak Detection


Ronnie Little, SPL Leak Detection

A pipeline integrity monitoring system cannot rely on a single parameter such as sight or smell to detect a problem. The system must be reliable (no false alarms) and capable of quickly recognizing and responding to problems. The SPL1000, is designed to monitor the status of a pipeline in real-­‐time. It will detect and send an alarm to inform the operator of abnormal events, such as leak, natural disaster, and third-­‐party damage and pinpoint its location. The SPL1000 scans key parameters such as pressure and temperature hundreds on times per second. This results in fast and reliable leak detection and allows the pipeline operator to quickly react to prevent, or minimize, the environmental impact and property damage.

QA/QC – Cost versus Value


Holley Baker, Mistras Group, Inc.

"This presentation is intended to describe the quality assurance (QA) requirement in the mechanical integrity element of the PSM rule, what impact it has on design, construction and installation, and downstream effects of overlooking QA from a value versus cost perspective. It provides a review of QA issues including missed design opportunities, fabrication defects, non-compliance to configuration and dimension specifications, shipping damages that were not identified until after installation, and improper installations that adversely affected safe operation. Our industry can benefit from a clearer understanding of the regulatory view of QA. There remain many facilities that lack appropriately applied QA programs. This presentation will provide valuable insight into the specifics of proven QA programs and their relationships to conceptual and detailed design, vendor qualification, vendor surveillance, new installations and spare parts and will include recommendations for the resolution of issues regarding this topic. This presentation will explore the boundaries of acceptable and unacceptable reliance on vendors and suppliers, and will provide information relevant to upper management, middle management and field personnel. It will explain the value of defining, establishing and maintaining appropriate practices and documentation necessary for the quality of critical assets."

SURF RBI - Cost Effective Solutions to Mitigate Identified Risks


Eric Allen, DNVGL

SURF RBI continues to be an ever evolving subject as technology evolves, processes and procedures improve, and the user gains moreknowledge.As a follow up tothe API Inspection Summit presentation in 2017, "Subsea RBI – State of the Art Review," the purpose of thispresentation is to provide case studies of cost effective solutionsthat were identified in RBI processes. Case studies to be presented include: 1)SCSSVtesting optimization to reduce downtime and increase production; 2) SubseaCP hotspot modeling and frequencyoptimization to reduce costly offshore vessel time; 3) Real time riser fatigue monitoring using advanced ML andANN; and 4) Unmanned, automated and autonomous technology for conducting subsea inspection to deliver > 50% cost savings compared to current practices.

Subsea Inspection with Game Changing MEC Technology


Andreas Boenisch, Innospection Ltd.

"Corrosion is a constant challenge especially in ageing subsea assets. This presentation focuses on how the next generation MEC (Magnetic Eddy Current) technology and its applicable is able to fill inspection gaps in the oil and gas industry. The MEC technique and the following case studies on MEC application and field experiences shall be presented: Non-piggable Subsea Pipelines As most subsea pipelines are non-piggable, Innospection has developed an external fast scanning package based on a tethered MEC solution capable of accessing and scanning the non-piggable subsea pipelines, flowlines and manifold pipes. Subsea Umbilicals, Risers and Flowlines (SURF) Externally coated subsea assets like caissons, risers, flexible risers can be inspected by the range of MEC-Combi inspection tools with high level of defect detection."

In-Line Inspection of Shut-In Pipelines


Shabbir Safri, Kuwait Oil Company

Kuwait Oil Company(KOC) maintains a large network of pipelines to transport Gas and liquid from gathering centers. Some of the pipelines are shutdown due to operational. It is not possible to carry out ILI for such pipelines using conventional free-swimming tools even though the pipeline are piggable. A production field including 2nos. oil pipelines were shutdown urgently. Mothballing could not be carried out immediately; hence, the integrity for the pipeline for safe operation required to be established. Various options were analysed with respect to the inspection, modification/support service requirements and time/cost. A plan was put in place in consultation with the ILI provider and both the pipelines were successfully inspected. This presentation describes the process and how challenges were overcome to carry out integrity inspection.

Value of Equipment-Inspection Test Plans for New Build Drilling Rigs


Steven Snyder, Transocean

Given varying templates, formats and structure used across the drilling industry on new build rigs, the creation ofproperly prepared, executed and controlled(ITP's) is an important map to success. Best practices that should be adhered to when preparing an ITP's, which also assist OEMs as they support manufacturing and assure quality of well control and drilling equipment installed on new build drilling rigs will be presented. Also, lessons learned & opportunities for improvement in complying with API standards orother reference standards/codeswith proven approaches before manufacturing starts with fully engagedVendor Surveillance Inspection personnel, working in tandem with project QA/QC management.Concluding with a review-discussion of IADC published guidelines relative to Manufacturing Record Book (MRB) and standard minimum contents includingITP's.

Advances in Nondestructive Assessment of Used Oilfield Coiled Tubing


Roderic Stanley, NDE Information Consultants

Used coiled tubing is damaged by corrosion, mechanical means, is difficult to inspect, and prone to field failures. Conventional NDE consists of several non-contact methods but knowing when to inspect as the tube fatigues is problematic. Equally important when assessing signals from NDE is the relation between MFL signals and their relation to the accumulated fatigue in the tubing, since it is operated in fatigue with 2-3% strain. Algorithms were produced (neural nets) to recognize MFL signal attributes from known imperfections, and then relate them to consumed fatigue that added to the tubing each run, and finally to determine when the tubing string should be withdrawn from service. This is the link between NDE and the material’s performance for this product that reduces downhole failures.

Popular O&G inspections using PAUT and TFM


Dillon Smith, M2M NDT, Inc.

Flange-, pin-, bolt -inspections are growing applications of the NDT market. There are currently numerous techniques for the inspection of sealing surfaces using regular phased-array ultrasound techniques (PAUT). M2M has implemented multiple total focusing method (TFM)techniques for theinspection of these structures. This article describes how the inspections can be achievedwith higher resolution and repeatability using TFM-capable flaw detectors. A comparison between standard PAUT and TFM imaging is also discussed. As both of these ultrasound techniques have pros and cons depending on the inspection case, the competitive advantage of offering bothin portable units is illustrated.

Planar Array Tool for Volumetric Surface Defect Detection and Measurement


Paul Lott, Exxam Systems LLC

"The problem of protecting in-service surface production systems and safe operationrelates to the need for adequate information, diagnostics, and prognosis of conditions necessary for calculating the remaining life before the onset of a warning, critical or limit state. This is a four level information problem. The most important information required is: Level 1- Is there any damage? Level 2- Where is the damage located? Level 3- How bad is the damage?Level 4- How will the damage affect the remaining useful life? An electromagnetic planar array tool has been developed forcorrosion detection and measurementon in-service, insulated surface production systems. This significantly advanced technology addresses the first threelevels by externally scanning for internal and external anomalies.and characterizing theirseverity wiyhout insulation removal.."

Ensuring Piping integrity for Oil & Gas Asset Performance Management


Haitham AlKanderi, Kuwait Oil Company

Ensuring integrity of process piping systems in Oil & Gas facilities is a key issue with respect to the process, business, safety and the environment.Enhanced asset performance can only be achieved by robust piping integrity management program.This presentation highlight a methodology to identify & assess condition of critical piping system in presence of high water/moisture content along with corrosive gases like H2S/CO2. Critical piping were identified based on the service guidelines provided in API 570, past failure history, material of construction, chemical injection location and corrosion monitoring. The condition assessment done by MUT/LRUT/Radiography.Moreover, this methodology enables Integrity Managers & Engineers to take timely decisions for maintaining piping integrity and enhance Asset performance in a cost-effective way.

CLASS and CAIP oil tanker survey using drones and software


Patrick Saracco, Cyberhawk Innovations

Cyberhawk completedthe first full CLASS and CAIP inspection of 19 tanks using a drone, achieving “no objection” from the American Bureau for Shipping. Requirements include close visual inspection and thickness measurements. Cyberhawk will discuss how drones minimised the risks of traditional access methods (transportation, setup and removal, personnel requiring to climb on/off scaffolding and potential damage to the vessel’s tank coatings). FPSO operators will hearhow 19 tanks were inspected by two people in 21 days, versus more than 30 people in 70 days. Using drones also led to a 50% cost reduction, allowing US shipyards to become more competitive in project bidding. The presentation will also cover how the inspection results were digitised and hosted in sector-specific cloud-based asset management software.

Unexpected SCC failures on high pressure 316SS offshore block valves.


Ria Khan, In-Corr-Tech Ltd.

"Medium and High pressure block valve fittings are common to all natural gas production platforms. Unexpected numerous failures were observed on 15 out of 242 valves across eighteen well flow lines located on an offshore platform. The 3/4"" 20,000 psi rated block valves were installed in 2008 and in sweet gas service. Investigations revealed that the 316 SS fittings were particularly susceptible to external ClSCC resulting in leakage and shutting in of numerous wells. Metallurgical analyses confirmed the valves were not solution annealed, but supplied in the strain hardened condition. Cracks were extensive, transgranular and originated from the internal threads. Recommendations were implemented and a NDE scheme was prescribed for all the other assets. The findings 1 year onwards and the lessons learnt are discussed."

Evolving a Proactive Corrosion Management System to Drive Inspection


Kenechi Ojemeni, Shell Petroleum Development Company

A review of the existing Corrosion Management System (CMS) determined that the poor and ineffective implementation of the CMS could be attributed to a myriad of factors. This paper captures the deficiencies of most systems and defines smart processes and activities which can be implemented to drive a more proactive corrosion management strategy. The extensive implementation of routine maintenance and inspection activities in most facilities is largely insufficient and clearly distinguished from proactive corrosion management. Focus will be given to issues around the threat identification / assessment culture and barrier selection and optimization as it forms the bedrock of any sound corrosion management system. The successful implementation of the improved Corrosion Management System in some facilities have yielded tremendous benefits and improved asset integrity.

Erosion in bypass of level Control Valve in gas plant


Hatam, Mehraz, Saudi Aramco

The present study has been conducted to investigate the failure of one inch bypass line of level control valve (LCV) in gas plant. The bypass is exposed to high pressure gas condensate with maximum 1.3psig H2S from NGL and leaked after 16 years in service. The investigation was conducted in laboratory has advanced grinding and polishing equipmentand failure type with its possible root causeswere identified,also recommendations and upgradingmaterialto prevent reoccurrence were well explained in this paper.

Localized Corrosion Inspection Locations for HF Alkylation Unit in Refinery


Huang Lin, Lloyd's Register Energy Americas, Inc.

Due to the characteristics of HF acid corrosion, HF acid corrosion is often localized in an HF Alkylation unit in the refining industry. The locations for HF localized corrosion are usually difficult to be predicted. It is one of the biggest challenges for inspection to perform piping inspection in an HF Alkylation unit. It is quite often that 100% coverage is required to perform piping inspection to address the concern for localized corrosion. This presentation discusses various mechanisms that result in the localized HF corrosion. Based on each mechanism and industry experience, typical localized inspection locations are recommended, which can help optimize the piping inspection program and reduce the cost.

Real-time Distributed Monitoring & Measurement for Pipeline Asset Integrity


Tara Merry, Baker Hughes, a GE Company

Pipeline events cost the Oil Gas industry billions of dollars each year. Leaks can result in major incidents, negatively-impacting the safety of humans and the environment, and costing businesses their reputation and profitability. The integrity of pipeline assets can be managed more efficiently and effectively than ever before. Technological advancements combining fiber optic sensors and cloud-based software can optimizes asset integrity through distributed real-time monitoring of pipelines. New solutions can connect operators to the assets they manage in real-time by performing multiple-variable analysis (acoustic, temperature, strain) to discern real events from false event conditions. Access to information about critical pipeline issues before they start, or immediately as they occur, allow operators to benefit from: reduced false positives, improved detection of and response to leaks.

Suitability for Service: Undocumented Pressure Vessels,and State Specials


Daniel Schardine, Applied Technical Services, Inc.

It is not uncommon for owner/users to encounter undocumented pressure vessels in their mechanical integrity inventory. Undocumented pressure vessels are also bought and sold in the used market. The significance, potential risk , and potential value of this subset of equipment is often poorly understood. This presentation discusses options to ensure the suitability for service and jurisdictional compliance of these vessels. Topics to include: definition and identification of undocumented vessels and state specials, development of inspection plans/protocols, inspection and examination procedures, engineering evaluation and fitness for service assessment, repair and alteration considerations, and typical state special requirements.

Methods for Mitigating Internal Corrosion


Lance Witt, Integrity Measurement & Control

This is a presentation on industry standards for mitigating internal corrosion specific to flowing and static pipelines, separators, and storage tanks. The emphasis will be on how to develop a mitigation plan based on data collected from the corrosion monitoring methods. The mitigation methods will include the injection of chemical inhibitors, scavengers and biocides and the use of pigging and cleaning programs. The pros and cons for each method are laid out specific to each application. How is the mitigation method proven affective? Cautions are noted where a chosen method may have risks and lead to poor results. Location, location, location ….visual examples will reveal where and how to apply a chemical mitigation agent for proper dispersion and distribution within the process. Examples will be presented to showcase poor station design as well optimal design.

Engineering Analysis of Backfilling Practices for Pipeline Maintenance Activities


Aaron Dinovtizer, BMT Fleet Technology

Integrity management programs include inspection and assessment processes that lead to remedial action decisions. Remediation can include excavation of the pipeline to remove, recoat, reinforce or contain identified damage or degradation features. Existing Industry standards and recommended practice do not provide detailed guidance on excavation and backfilling practice. Recent incidents and research related to unsupported spans buckling/wrinkling resulting from post backfilling bedding material consolidation/compaction have been used to developed useful guidelines related to safe excavation and backfilling procedures considering pipe geometry, grade, product and internal pressure.

Full-Scale Testing to Develop a Pipeline Leak Rate Estimation Tool


Mark Piazza, Colonial Pipeline Company

Cracks in pipeline steels represent a primary integrity threat being addressed in asset integrity management programs. Pressure cycle induced fatigue cracking is a significant concern for liquid pipeline operators. The potential exists for the fatigue process to result in cracks propagating completely through the pipe wall and releasing product. Tools for estimate the leakage rate and/or total release volume are important in evaluating crack consequence, operational responses when incidents occur, and remedial action strategies and timelines. Leakage rates through pipeline fatigue cracks have been experimentally measured, demonstrating that measurable leakage does not occur at low pipe internal pressures and increases in a nonlinear trend with pressure. The experimental data are being applied to theoretical engineering models to predict leak rates and estimate release volumes.

NDE Performance Verification for Pipeline Operators


Stuart Saulters, API.

In 2017, a group of pipeline operators came to API for assistance in helping develop a performance verification program for NDE technicians, specifically those involved in pipeline projects and repairs. While the technologies may be the same, the applications and anomalies looking for can be drastically different. For this reason, a new effort began to provide verification for NDE technicians performing work on pipelines. This presentation will detail the work to date.

Managing Corrosion in Slug Catchers


Mandar Kulkarni, Stress Engineering Services, Inc.

Slug catchers are employed to accommodate liquid slugs at the exit of gas pipelines with mixed phase flow. These sometimes suffer from internal corrosion due to a variety of mechanisms. Depending on the severity and extent of corrosion, the repair, which could be weld build-up or composite reinforcement, can become expensive.

A fitness for service assessment of such a slug catcher is presented. Analysis was initially performed to classify corrosion defects based on severity by performing hand calculations per API 579-1/ ASME FFS-1 Part 5. This was followed by a more detailed Pipe Stress and FEA analysis of select components. For composite repairs, FEA analysis aids with the design of an optimal custom reinforcement of each corroded section by looking individually at each specific feature.

Improved Methods for Estimating Fatigue Life of ERW Pipelines


Aaron Dinovitzer, BMT Fleet Technology

The fatigue of axial crack features present in ERW weld seams and in the pipe body can be a significant threat to pipeline systems. The material and full scale testing research described in this paper has developed and demonstrated fatigue crack growth rate material resistance and some stress intensity factor formulations representing the fatigue driving force that improve fatigue life estimates. The recommended treatment can be adopted in API 579 to reduce conservatism of defect fatigue assessment and thus focuses integrity management and remedial action activities and budgets on features that pose the greatest threat to pipeline integrity.

Pipeline Dent Integrity Management Guide Development - API RP1183


Mark Piazza, Colonial Pipeline Company

Industry research and development has defined techniques to characterize, assess and remediate dent features. This information is incorporated in a recommended practice (API RP 1183) for dent management and thus focus inspection and maintenance activities making them more effective. In the long term, this research could be incorporated by reference in CFR 49 Parts 192 and 195, as the current criteria for dent/deformation response and repair is too conservative, requiring non-injurious dents to be excavated and repaired, which shifts resources unnecessarily from those dents that really have the potential to fatigue and leak.

Understanding Crack ILI Performance Using In-the-Ditch NDE


Steven Bott, Enbridge, Liquids Pipelines

Successful implementation of crack ILI to manage crack threats on transmission pipelines can be affected by many factors that must be considered when verifying inspection performance. For example, differences in reporting thresholds and capabilities between crack ILI and NDE platforms or poor quality NDE can lead to incomplete or inaccurate understanding of tool performance. This presentation will leverage extensive Enbridge crack ILI and field NDE results to demonstrate how robust inspection and program performance measurement is important to having effective and efficient crack management programs. In addition, links between demonstrated tool performance and crack management best practices as discussed in API 1176 will be discussed using both Enbridge results as well as results from the PRCI project NDE-4E.

The Digital “Pig & Dig”: What? Why? And How?


Whitney Flora, Mobideo

Understand what digitalization is and how it can be applied to the Pipeline industry, In this presentation, we will explain what digitalization is and how it can be applied to provide benefits and REAL savings to the pipeline industry. A customer case study will be presented to illustrate a real solution that can be delivered today with immediate benefits related to: Improved adherence to schedule; Improved manageability of evolving scope; Improved resource utilization; Reduced manning levels; Improved quality and safety; Elimination of paper in the field; Automated and accurate reporting; Reduction of lost time between digs; improved data collection for post “pig dig” review; Improved planning capability; Process improvement and standardization across an organization; Increased efficiency and decreased costs

Deformation Program Performance Evaluation


Syed Haider, Enbridge liquids Pipelines

Developing a practicable methodology to demonstrate that the deformation program is able to identify key threats effectively and efficiently is imperative to having a successful pipeline integrity management program. While crack and metal loss effectiveness and efficiency can be tested by comparing reported depths and estimated burst pressure, this is not straight forward for deformation and deformation with different types of stress concentrators. Definitions of effectiveness and efficiency that Enbridge has used for the deformation program reviews will be discussed. The effectiveness of different types of regulatory and Enbridge criteria will be shared to demonstrate the requirement for engineering critical assessment as part of effective and efficient deformation management program.

A practicum on pressure testing - Compilation of best practices


Sheri Baucom, RCP, Inc

Pressure testing is one of the oldest methods of ensuring integrity of pipelines. Because of this, there exists a massive amount of information on the topic, some of which is outdated, misunderstood, inconsistent with other information sources and in some cases incorrect. This presentation will be based on a guidance document that seeks to: rectify the issues stated above by providing a comprehensive guide to pressure testing best practices drawing the distinction between gas and liquid code, current and proposed ; provide resolution and clarity where industry documents conflict, and be utilized as a tool operators can utilize to review and update their internal procedures. It will draw from already-available resources created by industry-recognized organizations as well as internal and external subject-matter-experts.

Data Integration to Meet the Requirements of CFR 195


Stacey McBride, Pivvot

According the Final Rule published by PHMSA, under review by the current administration, regarding the Safety of Hazardous Liquid Pipelines, operators must begin to integrate all information about attributes from a hazardous liquid pipeline, identify spatial relationships among inconsistent information, and go beyond simply storing data in their GIS, but analyze it for relationships. This session will explore the rule in detail uncovering specific attributes required for integration and timing of near-term enforcement of the rule. It will also uncover a new approach to integrating spatial data across systems quickly, efficiently, and securely to meet the required minimums. It removes the complexities of retrieving information from a traditional GIS – allowing analysis by department and offering a faster path to compliance of CFR 195.

Approaching API 653 Tank Internal Inspections as Business Opportunities


Lennar Perez, CITGO Petroleum Corporation

Many owner/operators and inspection companies approach mandatory API 653 internal inspections with a onetime cost perspective in mind. Not looking at long term opportunities to increase storage capacity often leaves potential throughput revenue or supply chain cost savings on the table. Opportunities to reduce “tank bottoms” and increase filling capacity on the upper courses for internal and external floating roof tanks are numerous and often overlooked. “Tank bottoms” or “heels” are the normal product levels required to keep flotation on Internal Floating Roofs when the tank is near empty. Flotation helps maintaining vapor emissions to a minimum. Modifications to gain working capacity vary from high costs to really inexpensive repairs. High level alarm calculations are critical. Different internal floating roof vendors offer different flotation line, pontoons, support brackets, and seal profiles. While many look at price to be the determining contract award factor for new floating roofs, low profile roofs can save in the long terms by increasing working capacity.

Corrosion Under Insulation in Pipelines. A Case Study.


Bernardo Cuervo, G2 Integrated Solutions

Thermal insulation over coating is effective, most of the time, but corrosion under insulation (CUI) may occur and brings a threat. In this presentation, a case study will be presented that addresses a pipeline that is subjected to CUI. We will review important considerations, like corrosion rate, temperature, and water sources. Finally, the selection of the proper ILI technology, fitness for service assessment, remaining life calculation and reassessment interval are presented. It is important to notice that managing the integrity of a pipeline is not really about what you found and responded to using ILI results. The true integrity of the pipe is based on how confident you were about the features that remain in the pipe that you decided not to respond to.

Mobile Reporting and Tracking for Improved Pipeline Integrity Management


Rana Ghosh, Intertek

A big challenge in dealing with pipeline integrity is the lack of traceability of pipe sections and correlating inspection and ILI data. Pipelines are built with pipes from different mills in various locations across the globe. Providing pipeline owners the ability to capture and track high quality pipeline data through all phases, including manufacturing, construction and operation is required. Mobile field inspection and reporting management solution increases the overall productivity during the manufacturing and in-service phases by reducing the time to document inspections and streamlining the workflow. By combining traceability and inspection into one task, owners and operators achieve full transparency into the manufacturing process retain a digital record which is vital for assurance and compliance purposes and accessible anywhere in the world.

Reverse Engineering for OSHA Compliance when Design Documentation is Missing


Brian Macejko, The Equity Engineering Group, Inc.

The Occupational Safety and Health Administration (OSHA) requires owner-users to maintain essential documentation authenticating adequate design and maintenance of pressure vessels and storage tanks. Unfortunately, it is not uncommon to find equipment operating with minimal or no documentation. This has become even more common in recent years with the re-purposing of assets for use in new midstream facilities. Suitability-for-Service (SFS) is the process of performing inspection and engineering to obtain OSHA compliance for fixed equipment lacking documentation. This presentation will outline the general SFS process and provide a number of case study examples of application in industry.

The Unique Inspection Requirements of Bolted CHIME Tanks


John Cornell, H.I.R. Technical services

For many years API 12B Chime tanks have been inspected using either API 653 or API 12R1. While both of these documents are to be referenced during an inspection of a bolted tank, they are not complete since they deal mostly with welded or riveted tanks. How to inspect a bolted tank is not an uncommon question and with more and more bolted tanks coming on-line every day, we must provide detailed inspection requirements as to both support our industry and to keep our workers and the environment safe. Industry has taken steps to supply assistance with the inspection of bolted tanks and we aim to cover the latest information available .

Effect of Pipeline Deposits on MFL Sizing Accuracy of Pinholes


Joel Falk, Desjardins Integrity Ltd.

A frequent issue with gas pipelines is the presence of debris, often black powder, which can potentially affect the sizing accuracy of MFL tools in two ways. First, any type of deposits can cause liftoff of the sensor heads. Secondly, iron oxides ( particularly magnetite) located in a metal-loss anomaly can affect the magnetic signal of the anomaly. In addition, it is possible that ferromagnetic deposits could build up on the exterior of the pipeline under the coating, and may also affect MFL readings. If any of these situations resulted in a lower-amplitude MFL signal, the result would be an under-sizing of the anomaly. An investigation into the potential effects of pipeline debris on pinholes was performed, using both theoretical and experimental data.

A Proven Methodology for Integrity Assessment of Facilities Piping


Juan Carlos Ruiz-Rico, Det Norske Veritas (U.S.A.), Inc. (DNV GL)

Integrity assessment of facilities piping frequently encounters challenges such as complex systems with varying materials and sizes, cased road crossings, thermal-insulated, electrical interference, underground sections with soil-to-air interfaces, and interacting CP systems. The assessment methodology presented combines the principles of API Piping Inspection Code 570 and NACE Direct Assessment (DA) Process for buried pipe. The presentation discusses this risk-based and software-supported methodology, covering the compilation in an inspection program of condition monitoring locations, corrosion rates, remaining life, reassessment interval, and the enhancement of results with finite element analysis (FEA) to perform fitness-for-service (FFS), addressing findings identified with visual inspection and nondestructive examinations (NDE). This methodology has been successfully applied and proved in the industry since 2005.

Improvements in crack depth sizing and benefits for integrity management


Summer Ruddick, NDT Global LLC

Data collected from In-Line Inspection tools is often the foundation of Integrity Management Plans (IMP) and determines the response and mitigation efforts required. As the foundation, the IMP is only as accurate as the data used, considering the accuracy of the ILI results will influence the pipeline operation, the tool tolerances and uncertainties need to be taken into consideration. Nevertheless, for deeper crack features, >4 mm, a degree of uncertainty remains in regards to depth sizing. Deep features represent a higher risk; therefore, it is critical to reduce the uncertainty for deep features. The latest improvement for crack depth sizing, Enhanced Sizing, removes the uncertainty for deeper features; as this methodology is capable to size cracks for the entire WT range.

Use of Drones to Inspect Aerial Pipeline Crossings


David Hunter, Pond & Company

Pipeline Aerial Crossings remain a change for access. Unmanned Aerial Vehicles (UAVs)offer an opportunity to perform close up visual inspection without putting personnel at risk. From a corporation's Health, Safety Environmental Policy (HSE), UAVs should be a part of every company's inspection plan, from a cost, safety and quality of inspection standpoint. This presentation will discuss one case history regarding performing an aerial inspection to me regulatory requirements, as well as providing superior inspection information to other methods

Guided Waves for Structural Health Monitoring of Pipeline


Sang Kim, Guided Wave Analysis LLC

Permanently installed monitoring sensor (PIMS) using guided waves has been developed and installed for structural health monitoring of pipeline. Monitoring of structure can be done with 3 different methods ---1) Inspecting pipeline at the same location marked, 2) Permanently installing a magnetostrictive strip on structure and inspecting it with monitoring probe, and 3) Permanently installing both magnetostrictive sensor and monitoring terminal. The 3 monitoring methods using magnetostrictive sensor (MsS) was performed and their results are compared for guided wave monitoring of structure. This presentation is designed for API inspectors, maintenance management personnel, and facility operators.

Remote detection of stress magnetisation to inspect and map pipelines


Paul Jarram, Speir Hunter Limited

This presentation outlines recent developments in an emerging non intrusive sensing technique developed to detect localised abnormal pipe wall stress by mapping variations in the earth’s magnetic field around pipelines. Corrosion, metallurgical defects and ground movements result in areas of increased localised stress in pressurised pipelines and a direct relationship has been described mathematically relating magnetic field characteristics to the magnitude of stress due to magnetostriction. The method is non invasive and reports localised stress as a percentage of material specified minimum yield strength, its geometric centre, accurate positioning of girth welds and 3 dimensional mapping of the pipeline route including depth of cover all to cm accuracy. The benefits and a series of case studies are described to illustrate the accuracy of its predictions.

Application of Leak Detection


Chika Timothy Onwuchekwa, Halliburton Energy Services, Nigeria Limited

This paper examines the application of leak detection to control pollution in the Niger Delta region of Nigeria. Spills/pollution arise due to design faults, or deliberate damage in act of vandalism. The Niger Delta region has become hugely polluted in recent times due to large amount of uncontrolled oil leaks that results to spills. It is important that inspectors, engineers and managers of pipeline and process facilities take lead in the application of proven leak detection methods to eliminate or reduce the occurrence of leaks to an acceptable or tolerance level. There are various methods of leak detection applications, but this review is limited to helium mass spectrometer for process facilities and acoustic monitoring of change in sound generated from a given pipeline section.

In-line screening of small diameter pipelines using free-floating smart sensors


John van Pol, Ingu Solutions Inc.

Advances in micro-electronics and machine learning open the door to a new method of in-line pipe inspection: small free-floating smart sensors moving in the flow, capturing critical data and enabling operators to optimize pipeline performance, detect anomalies, and flag changes in pipeline condition. The free-floating nature and low costs of these sensors enable frequent screening over the full length of the pipeline under operational conditions. This presentation will show the results of the screening of 20+ small diameter (2 to 8 inch) metallic and composite pipelines under operational conditions using the first economically accessible solution on the market today, the Pipers™ technology. The Pipers™ are equipped with an IMU and magnetometer, a combined pressure and temperature sensor, and an advanced system for acoustic leak detection.

The Inspection of Vented, Fiberglass Storage Tanks


John Cornell, H.I.R. Technical Services

The purpose of this presentation is to provide procedures for conducting periodic preventive maintenance inspections along with the more comprehensive inspections that are required and that must be performed by a Trained Inspector as relating to inspection of fiberglass reinforced plastic (FRP) atmospheric tanks and vessels in corrosive industrial and commercial service after being placed into services or experiencing a change of service. The procedures are intended to: minimize maintenance costs, ensure compliance with environmental and safety requirements, minimize system failures and ensure that proper engineering, construction and maintenance practices are in place.

Pipeline and Tank Floor Inspection with Game Changing MEC Technology


Suyee Mo, Innospection Ltd

Corrosion is a constant challenge especially in ageing and insulated pipelines. This presentation focuses on how the next generation MEC (Magnetic Eddy Current) technology is able change the way pipelines can be inspected and fill inspection gaps in the industry. The technique and case studies on MEC application with field experiences shall be presented: Non-piggable Subsea Pipelines. Innospection has developed an external fast scanning package based on a tethered MEC solution that is capable of externally accessing and scanning the non-piggable subsea pipelines, subsea flowlines and manifold pipes. CRA-clad / Heavy-walled / Non-metallic lined Pipelines The MEC-Pig Internal Pipeline Tool currently being developed shall be able to inspect through CRA-clad and non-metallic lined pipes with coating that are currently not inspectable by existing techniques.

Capturing Best Practices for Third Party Inspections of Facilities Construction


Reena Sahney, Enbridge

The North American pipeline industry has significant challenges in a time of economic uncertainty in energy prices as well the potential for loss of valuable experience due to shifting workforce demographics. The INGAA and CEPA Foundations have a number of initiatives underway to capture and share best practices; in particular, there is emphasis on improving quality during the construction of pipelines and facilities. The initiative described in this paper will compile a body of knowledge and capture best practices as they relate to third party inspection during the construction process for facilities. This work is an extension of the “Practical Guide to Pipeline Construction Inspection” which was released by the two Foundations in 2016 and has become integral to the API 1169 Inspector Certification program.

Improving Safety Through Technology and Innovation


Monica Golden, Insitu

Embracing new technology significantly de-risks operations and increases productivity. Remote sensing provides reliable and repeatable data sets that can be compared in real time to help determine trends. By integrating these assets into work flow processes, maintenance and resources can be prioritized. Managers realize benefits by combining UAS, cutting-edge sensors, and data analytics into pipeline safety management systems. Present: Safety/security (24/7 site surveillance); Operation efficiency (aerial pipeline survey, right-of-way with automatic change detection); Compliance (water/gas leak detections); Cost-effectiveness (no driving or flying manned aircraft to remote/inaccessible pipeline infrastructure). Future: Remote sensing operations bring situational awareness of infrastructure directly to headquarters/disseminate decisions back to the field in real time. Machine-learning and analytics enable factual decision-making Recurring/mundane maintenance inspections and surveying are conducted autonomously, enhancing site safety.

Using Satellite-Based Hyperspectral Imagery for Pipeline Integrity, Leak-Detection and Compliance


Peter Weaver, Orbital Sidekick

Technology miniaturization, combined with a persistent cost decrease for data processing, has opened the frontier for deployment of hyperspectral imaging for detailed, objective, analytical inspection and leak detection for pipeline assets. Appealing to compliance and asset integrity personnel, as well as technology mavens and general management alike, this presentation explores how of hyperspectral intelligence enables leak detection and hydrocarbon speciation while meeting DOT pipeline inspection compliance obligations. The presentation includes examples where pipeline leaks, undetectable by conventional monitoring, have been found using Spectral Intelligence. An imager owned by Orbital Sidekick (OSK) is deployed on the International Space Station (ISS). This latest development in satellite-based hyperspectral imaging will be shown as an outrageously powerful and cost effective means for data gathering and pipeline stewardship.

DNA Testing, What is it and how can it help?


Tom Pickthall, EnhanceCo INC

Advanced microbiological testing protocols are increasingly being used to identify and correct corrosion issues for energy, storage and commercial applications. A discussion of what DNA testing methods are available and how the results can be useful in correcting corrosion related problems will be discussed. A forecast of advances in both the test methods, and predictive analysis based on "Big Data" used in the future will be examined based on the authors experiences.

Rectifier Selection: “ What’s Right for your Application”


Don Olson, IRT Integrated Rectifier Technologies Inc.

Cathodic Protection Rectifiers are usually the only visible piece of equipment indicating that an impressed current Cathodic Protection system may be in existence somewhere in the area. They can be found in remote isolated areas, farm pastures, facility electrical / control rooms, residential back alleys and even school / playground areas. These CP systems are used in various industries / applications and can be stand alone or part of an overall CP system network. Rectifiers are the controlling factor when supplying Cathodic Protection to structures that can be subject to external corrosion problems. The content of this presentation is to provide a little insight into the design considerations and variations available when choosing the right Cathodic Protection Rectifier for your specific application.

Vendor Compliance in Purchasing Pipe: Understanding Fusion Bonded Epoxy


David Hunter, Pond & Company

There are many types of appropriate coating systems, such as two-component liquid epoxies and urethanes, but single- or two-layer fusion-bonded epoxy (FBE) is most often used for buried steel pipelines in the U.S. The durability of this coating type for this environment has been well proven. An advantage of using FBE over liquid applications is that the materials can be applied in a highly controlled environment at fairly high speed which tends to drive down overall cost of application.

This article discusses the fundamental steps of FBE application, some advantages and disadvantages, and some basic inspection criteria for a quality application.

The Next Generation CP for Double Bottom Tanks has Arrived


Louis Koszewski, US Tank Protectors, Inc.

A new and innovative approach allows for the electrical isolation of the old tank bottom and dead shell and old tank bottom during the re-bottoming process, or on existing double bottom tanks. No longer will there be concerns over consumed CP systems between the tank bottoms, as CP current from external CP systems can now pass right through the old tank bottom to get to the new tank bottom. A conductive type liner can now be used as release prevention, while allowing CP current to pass through to the new tank bottom. Where an "El Segundo" is used, this new approach can be utilized to allow for extended API 653 internal inspection intervals by allowing cathodic protection to the "El Segundo" tank.

Codes & Standards Review of Electrically Resistive Pipeline Coatings


Bob Buchanan

Pipeline corrosion protective coatings are electrically resistive to perform as an effective coating. However, resistivity levels vary depending on the coating technology employed and the conditions of service. Electrically resistive coatings, or high dielectric strength coatings, cause some confusion when they must also be compatible with cathodic protection which, requires the flow of cathodic current. This paper will summarize various national and international codes and standards about coating attributes, performance requirements and application parameters. It will also review test methods which are used to measure performance, including electrical resistivity of coatings, and said attributes of the coatings with respect to how the codes and standards comment on certain performance requirements, independent testing and manufacturer and user sponsored research into coatings and their electrical interaction.

The Mechanical Aspects of Internal Corrosion Monitoring


Jerry Brown,Brown Corrosion Services, Inc.

Internal corrosion and erosion is a problem with pipelines. Internal metal loss and pitting is ongoing. moving the majority of corrosion failures to the inside of the pipelines. With the improvements in inspection techniques and advanced internal monitoring techniques, the issue remains how do you insert and remove the coupons and probes, collect the samples and perform this work in a safe, efficient, and consistent manner. Dependency of the weight loss coupons and probes to satisfy data for integrity programs, adjustment of the corrosion control techniques in a timely ,manner is essential. This presentation shows the actual mechanical equipment in a variety of production, gathering, and pipeline facilities illustrating different methodologies of corrosion monitoring, corrosion control monitoring and sampling.

Dead Legs - Prioritization, Remedies and Failures


Jerry Brown,Brown Corrosion Services, Inc.

Dead legs in pipelines present many problems. As dead legs have no-flow characteristics, this can have exacerbated internal corrosion rates. Since dead legs are not usually affected by most corrosion control techniques, many failures, some catastrophic, have occurred. How to identify dead legs and prioritize dealing with the ones identified, is an ongoing problem. This presentation will define dead legs, understanding the risk they pose, a methodology to prioritize and/or eliminate them. Most integrity programs do not address the issue of dead legs. An example will be shown of a failure of a dead leg and the failure analysis to identify the corrosion mechanism that caused the failure as well as the human factors in not being aware, eliminating or inspecting the dead leg.

Use of Corrosion Coupons and ER Probes for AST's


Louis Koszewski, US Tank Protectors, Inc.

The use of corrosion coupons and ER Probes has been used under aboveground storage tanks. Long term studies have been performed showing that the coupons and ER probe elements used under aboveground storage tanks may not be representative of the actual corrosion occuring on the tank bottom. Tank bottom flexing during the filling and emptying of product creates different corrosion mechanisms on the tank bottoms that may not affect the coupons or ER probe elements.

Internal Corrosion Monitoring Methods


Lance Witt, Integrity Measurement and Control

This is a presentation of industry standards for monitoring internal corrosion specific to flowing and static pipelines, separators, and storage tanks. The methods will span from the use of various styles of coupons, to in-situ liquid and particulate collection, to monitoring techniques such as Electrical Resistance, Linear Polarization and Ultrasound. The availability of real-time remote data collection technologies is included. Caution will be emphasized concerning the potential effect of cathodic protection on the monitoring method and resulting data. Pros and cons for each method are laid out specific to each application. The risk for erroneous data due to choice of methodology is noted. Location, location, location …. visual examples will reveal where to install each type of monitoring technology for optimal results. Samples of collected data will be analyzed to determine the likely causes of corrosion. The monitoring techniques and methodology for collecting quality data will form the basis of the second presentation on mitigation methods.

Corrosion Control of Rural Gathering Lines – New API Recommended Practice


Drew Hevle

PHMSA has proposed regulations for previously unregulated rural natural gas gathering lines. API convened a committee to develop a recommended practice containing safety standards for the design, construction, testing, corrosion control, operation, and maintenance of onshore gas gathering lines in rural areas. The provisions are intended to complement the U.S. Department of Transportation’s (DOT) requirements for regulated onshore gas gathering lines in 49 C.F.R. Part 192. DOT established those requirements in a March 2006 final rule and initiated an effort several years ago to expand the scope to include certain historically-exempt gas gathering lines in rural areas. This recommended practice aligns with that rulemaking proceeding and is limited to onshore gas gathering lines in rural areas that are not presently regulated by DOT. This presentation will review the corrosion control requirements of the recommended practice, anticipated to be published prior to the conference.

Mechanical Integrity Evaluation for Gas Pipelines Capacity Augmentation


Anil Kumar Bhat, Vedanta Limited Cairn Oil & Gas

This paper summarizes the case study to analyze gas pipeline velocity limits constrained by the API RP 14E erosional limit criterion. While API erosional velocity is widely used in the oil and gas industry, it does not consider factors such as changes in pipe geometry, solids production and liquid content in the gas stream which leads to over-simplification of the limits. Pipelines can be operated at higher rates taking into account all these factors. This paper present advanced approach adopted for risk assessment required for capacity augmentation of existing gas pipeline, without compromising safety of the pipeline.

Using Advanced Analysis to Reduce Hydrogen Bakeout Times


Scott Bouse, Wiss, Janney, Elstner Associates, Inc.

Many companies in the Process Industries know that Hydrogen Bakeout is necessary before welding or grinding on carbon steels in sour service. However, few companies have a scientific basis for the required bakeout procedure, and instead rely on prior experience or guesswork to establish a bakeout plan. Even then, most references are intended to ensure a successful full-penetration weld repair, and do not account for actions that only influence the surface of a component. This presentation will cover some of the analytic approaches available to owner-operators, including shortening bakeout times when repair activities are local to one surface, or in areas such as flanges where the thinner nozzle neck serves as a ‘choke point’ preventing hydrogen diffusion from a heavier section.

Alternating Current Interference on Pipelines


Anthony Ashiofu, RK&K

High Voltage Power Lines (HVPL) produce an electromagnetic field which can be of great concern to metallic pipelines. Risks to Pipeline integrity and Personnel safety should be investigated whenever there are HVPL’s near metallic pipelines. Coatings on pipelines are usually used to protect pipelines from corrosion due to harsh environments. This presentation discusses the challenges of improved modern pipeline coating technology on the AC mitigation problem. This presentation also provides the approach for threat assessment, modeling and mitigation.

Hard Spots on Pipelines


Nigel Strike, Boardwalk Pipeline Partners, LP

Hard lesson learnt: BW investigated the root cause of a 30” pipeline that ruptured in Jackson MS, in the winter. Impact to the environment. Investigation in to root cause of the issue along with how it happened. Development of a testing procedure on similar pipeline containing the hard spots cracks to determine critical path for rupture and resolution of the issues found and safety factors considered.

Mechanical Integrity Program Development for New Construction


Matthew Caserta, Becht Engineering, Co.

Development of mechanical integrity programs is not new to the refining and petrochemical industry. Most of the experience related to the development of these programs is for existing process units that have many years of operating history. When new units are constructed or significant revamps completed, the mechanical integrity programs are typically left to be completed after the unit has been commissioned. Marathon Petroleum and Becht Engineering completed a project to implement mechanical integrity programs for 2 process units that were under construction. This project involved developing a damage review,integrity operating windows (IOWs), and corrosion control documents (CCDs). Building on the damage mechanisms, a risk-based inspection (RBI) analysis was completed and inspection drawings were created with condition monitoring locations (CMLs) assigned to piping and equipment.

HTHA Advanced Vulnerability Assessments, Inspections, and FFS Approach


Arthur Jensen, PBF Energy

PBF Energy has applied advanced HTHA damage vulnerability modelling of equipment and piping at 5 USA refineries using proprietary methodology from an engineering consultant. The results identified highest risk assets for prioritization of advanced NDE inspections, scoop sampling for laboratory examination, and asset replacements. The NDE methods include on-stream acoustic emission (AE) monitoring, on-stream ultrasonic examinations, and off-stream highly sensitive ultrasonic and magnetic particle examinations. Degradation consistent with the predictive modelling has been detected at early stages. We then apply FFS methods along with additional on-stream monitoring to enable safe operation until the assets can be replaced. These advanced practices have enabled PBF to reduce overall risk of HTHA and better prioritize inspection and capital replacement resources.

MI Fundamentals: Roadmap to Q1 Performance


Mariah Benedick, PinnacleART

Many Asset Integrity topics focus on application of cutting-edge point solutions. Many times these solutions can enhance existing, more advanced programs – however some operators are still struggling with the fundamentals. In an effort to re-engage operators that may be struggling in the 3rd or 4th quartile in terms of performance, this presentation will identify many of the basics of a solid Asset Integrity program and discuss how to develop a roadmap to bring your integrity program up to best in class – from the ground up.

Vibration integrity management – new tools to avoid fatigue failure


Hilmar Bleckmann, Wood

This presentation introduces an easy-to-use method to identify, assess and track piping vibration, a common integrity risk. Industry guidelines such as the Energy Institute’s “Avoidance of Vibration-Induced Fatigue Failure in Process Pipework” can narrow down high-risk areas and focus remediation efforts where they are needed, however, its application can be overly complicated. Engineers have been challenged to decipher conditions with spreadsheets to perform the required calculations – with varying levels of success. Spreadsheets have been prone to costly errors and inefficiencies when faced with large-facility calculations. New tools to perform risk calculations, track anomalies and avoid errors have been developed by the authors of the guideline, providing a quantitative risk assessment and mitigation strategy for designers, engineers, managers and operating personnel of pressure equipment facilities.

Making sense of piping vibration measurements


Hilmar Bleckmann, Wood

Excessive vibration in process piping of pressure equipment facilities is a high-impact integrity risk and common failure mechanism. Based on studies by the UK Health Safety Executive, 21% of hydrocarbon releases are due to vibration-induced fatigue failure. Piping vibration velocity measurements are often characterized as ‘acceptable’, ‘of concern’ or ‘dangerous.’ But what does this mean in terms of potential fatigue damage and associated fatigue life, particularly when the system under inspection is only operating intermittently? This presentation explores the relationship between vibration velocity measurements, dynamic stress and fatigue damage accrual and provides initial guidance on interpreting measured vibration velocity data, particularly for intermittently operating systems. The topic is relevant to inspectors, engineers, managers and operating personnel of pressure equipment facilities subject to vibration.

Process Piping Vibration Assessment and Mitigation


Scott McNeill, Stress Engineering Services, Inc.

A combination of piping flexibility, high process flow rates, multi-phase flow and flow obstructions can lead to excessive piping vibrations, resulting in fatigue failure. Case studies are presented to illustrate vibration assessment and mitigations. An assessment of heater outlet piping was performed using field-measured vibrations and a CAESAR II model. Additional support conditions were designed using the model and implemented in the field. Vibration data, retaken after installation of the additional supports, showed that the system passed fatigue analysis. Elevated vibrations resulted in small bore connection failures at the feed lines to an FCCU regenerator. Pressure pulsation and vibration measurements showed two dominant frequencies, both near 40 Hz. Analysis indicated that the frequencies were likely due to acoustic modes. Short-term and long-term recommendations were provided.

Spring Hanger Pipe Support and Maintenance


Chuck Thornton, Versa Intergrity Group

The API 570 Piping Inspection Code and API RP 574 Inspection Practice, ASME B31.1 Power Piping and B31.3 Process Piping Codes recommend pipe supports should be maintained. Since 2007, the B31.1, Chapter VII requires owners to know the condition of their pipe supports on the Covered Piping Systems operating within the creep regime. The presentation covers the lifecycle of a spring hanger pipe supports from design, installation, operation, inspection and maintenance and will discuss the main features of an acceptable inspection and maintenance program. Also, the importance of both visual and hands-on inspections during both “cold” and “hot” operating conditions is emphasized. Some examples of previous work will be shared to illustrate and reinforce problems with not only spring hangers, but pipe supports in general.

Performance-Based Assessment of an Incinerator Stack Using Field Measurements


Kenny Farrow, Stress Engineering Services Canada

ASME STS-1 provides guidelines for the design, fabrication, and erection of steel stacks, however there are no specific guidelines for the assessment of guyed steel stacks already in service. Furthermore, existing literature regarding the proper re-tensioning of guy wires is scarce or nonexistent. This procedure is particularly important for stacks that experience significant thermal growth. This effect is further exacerbated by directional wind cooling effects. This paper summarizes the effect of guy wire spacing, position, tension pattern, and operating and shutdown tension settings on the structural response of a guyed steel stack. Field tension measurements and laser scans are used to refine a finite element model of the stack. A performance-based methodology for lateral deflection is provided to guide fitness-for-service assessments and mitigation implementation.

ASME B&PV Code VIII-2: Background, Initiatives and Cost Savings


James Sowinski, The Equity Engineering Group, Inc.

The release of the 2017 edition of the American Society of Mechanical Engineers Boiler Pressure Vessel Code, Section VIII, Division 2 (ASME VIII–2) marks the 10th anniversary of the major rewrite to the codebook. The stated goals of the rewrite were to improve user-friendliness and breakdown barriers of its use, to make the codebook competitive with vessel codes in the European market, and to deliver new state-of-the-art design rules and concepts to the users. This paper will provide background on the rewrite of ASME VIII-2, the initiatives ASME has taken to promote the codebook to the pressure vessel community, and the means to achieve real cost savings for new construction of process equipment in the refining and petrochemical industries.

Common Pitfalls of a PRV Reliability Program


Chad Patschke, Ethos Mechanical Integrity Solutions, LLC

This presentation discusses opportunities for improvement (OFIs) in pressure relief valve (PRV) reliability programs frequently identified as part of API's Process Safety Site Assessment Program (PSSAP). The presentation identifies common areas for improvement through the various elements of a PRV reliability program including visual on-stream inspections, inspection at removal from the process, transportation and handling, as-received pop testing, shop overhauls, final acceptance testing and reinstallation. All too often, opportunities for improvement are identified during the PSSAP that would strengthen a site's PRV reliability program. This presentation covers the common gaps and opportunities to enhance a PRV reliability program.

IOWs - Implementation experience and lessons learnt


Vishal Lagad, Lloyd's Register

As refinery infrastructure matures and current human experience is replaced with younger expertise, enhancing plant reliability and safety is ever more demanding. IOW implementation is perceived in the industry as being expensive – prohibitive even, primarily due to additional monitoring costs and infrastructure needed. From our experience, mid- to small-scale refiners can also benefit from IOWs, using existing instrumentation and cost-effective, ‘out-of-the-box’ sampling and monitoring solutions to address most critical operational issues and pick off the ‘low-hanging-fruit’. Technological advances in the areas of sensing, data visualization and notifications along with technological leaps in software and data acquisition, can be easily leveraged to make IOW implementations much more affordable and expedient. We plan to share our experiences and lessons learnt along the way in implementing IOWs.

Seven Pillars of Mechanical Integrity


Steven Bolinger, Becht Engineering

This presentation describes the primary components or “Pillars” of a best-in-class Mechanical Integrity program. Each component is described in detail and implementation of the various sub-components is discussed. These components tend to be the major categories scored in a typical Mechanical Integrity program audit. In recent years significant emphasis throughout industry has been on the Corrosion Management component of Mechanical Integrity. Also, significant resources have been allocated to Risk Based Inspection (RBI) which often is utilized for the Inspection Planning component. These two areas of emphasis have often resulted in minimizing the other major components and potentially negatively impacting the overall Mechanical Integrity program at a site. This paper emphasizes the importance of all the major components.

Advanced Complementary HTHA Inspection and New API 941 NDE Guidance


Joseph W Krynicki, ExxonMobil Research and Engineering Company

Traditional HTHA inspection techniques based on currently published 941 guidance are undergoing significant changes. Contemporary guidance is based on established technologies (e.g., TOFD) with application specific modifications and interpretation approaches, and, includes new techniques (e.g., TFM/FMC PAUT). The proposed 941 guidance is more comprehensive compared to the current document and has undergone significant modifications including, new techniques, inspection effectiveness and general application guidance. This paper will review these proposed changes to API 941 and show data from HTHA damaged material demonstrating the value of multiple and complementary techniques.

Operating small pipe


Josh Yoakam, HollyFrontier

A series of thoughts to encourage discussion about issues affecting the owners of small bore pipe. Simply reviewing the definition is not sufficient to promote better understanding, exploring different ideas may shed light on old problems and find opportunities for integrity improvements.

Solving the Mysteries of Critical Check Valves


Chad Patschke, Ethos Mechanical Integrity Solutions, LLC

This presentation addresses the mysteries around critical check valve (CCV) inspection programs. It addresses the Why, What, Where, Who, How, and When associated with identifying CCVs and developing a CCV inspection program. The presentation discusses the following: Reasons why most companies do not have a CCV inspection program in place yet; Defining CCVs and providing examples of components of different types of check valves; Previous industry incidents and failure data related to check valves; General criteria for identifying CCVs and where CCVs are commonly found in refineries; Inspection tasks/practices associated with CCVs; Roles and responsibilities associated with CCV MI programs (e.g., inspector, valve shops, operations, NDE techs); Typical intervals for CCV inspection/testing tasks

Phased Array Detection and Metallurgical Analysis of Creep Fatigue Cracking


Terry Haigler, Intertek

Routine inspections coupled with a good condition-monitoring program are a critical part of the maintenance and safety of piping systems. The detection and field evaluations of indications using a nondestructive technique are only part of understanding the significance of the indications in your piping. Intertek AIM will present a case study of a routine inspection that leads to a significant indication and the steps taken to analyze and eliminate the indication. Detailed discussions will be given on the NDE processes used to evaluate the indications including magnetic particle inspections, encoded phased array inspections, hardness values, field replications, and positive material identification results. We will also discuss boat samples and the metallurgical analysis performed in the laboratory to further evaluate the root cause of the indications.

Long Range Wireless UT Sensor Adoption: Corrosion Monitoring & Inspection


Steve Strachan, Sensor Networks, Inc.

Advances in low cost/long range wireless UT technology have given refineries an opportunity to augment manual inspection teams with installed wall thickness monitoring sensors. A challenge in deploying such systems is the ability to achieve sensor connectivity at a low cost to the plant infrastructure, allowing a dispersed amount of sensor points to exist across multiple process units. A wireless ultrasonic corrosion monitoring sensor was developed utilizing a long-range, low power, wide area network based on LoRa standard and star topology. Over one mile connectivity is being achieved across a number of refineries. Data is backhauled from the sensor to gateway and pushed to a cloud back end for data trending/analysis. This paper will review the development of this technology and deployment case studies.

ASME Section IX Welding - “Process, Procedure and Performance“


James F. Harries, Marathon Petroleum Corporation

ASME Section IX welding procedure specifications and welder performance qualifications are prepared and implemented to meet the requirements of various Construction Codes. Common mistakes identified during review of these documents include the omission and/or misapplication of ASME Section IX’s procedure and/or performance “variables”. Understanding these procedure and performance “variables” and how they relate to a specific welding process is crucial to successful completion of production welds. This presentation will provide an experienced driven discussion of ASME Section IX procedure and performance “variables” and their application. Examples of ASME Section IX nonconformance encountered during documentation reviews will be provide "lessons learned" to enhance understanding. Additionally, Construction Code requirements often overlooked by individuals new to ASME Section IX procedure and performance documentation development will be discussed.

Establishing Integrity Operating Windows (IOWs) for Refinery Fired Heaters


Aleah Toyokura, Quest Integrity

Understanding and establishing effective Integrity Operating Windows (IOW’s) is critical in the management of fired heater assets. IOW’s, as described by API 584, are a specific subset of operating limits focused on maintaining the integrity and reliability of process equipment. IOW’s address issues that involve process variables that, when not adequately monitored or controlled, can impact the likelihood and rates of damage mechanisms, leading to loss of containment. The establishment, implementation and maintenance of IOW’s employs a multi-disciplinary approach and should be considered an essential part of facility maintenance strategies. This presentation will provide an overview of the key components in establishing IOW’s, the levels of IOW limits, and the basic principles and application of API Recommended Practice 584 to achieve reliable fired heater performance.

A105/A106 Metallurgical and Brittle Fracture Considerations


Puneet Saggar, Llyod's Register

A sudden failure under the action of stresses in carbon steel grades like A105 and A106 is a concern for equipment, fittings and piping produced from these grades. Under normal service conditions, ductility is not a major concern, but during upsets or shutdowns and /or hydro testing, brittle fracture becomes a valid concern. Equipment material selection engineers, inspectors and at times engineering managers can play an important role in mitigating this issue. During design stages, simpler metallurgical and material properties fundamentals can help mitigate the issue. Past the service life, any changes should pass through technical evaluations along with material property and steel melting practice related information during the ordering of these materials including the conditions that may lead to their exposure to colder temperatures.

Elimination of Backing Gas in Austenitic Stainless Steel Welds


Charles Patrick, ALS Maverick Testing Laboratories, Inc.

Open root welding of austenitic stainless steel with gas tungsten-arc welding (GTAW) is typically performed using an inert backing gas for purging, such as argon, to protect the root pass from atmospheric contamination and oxidation. In many cases, using a backing gas for purging is impractical due to system design, access limitations, personnel safety, schedule and various economic factors. After extensive application research, development and testing the need for backing gas has been eliminated for open root welding of austenitic stainless steel using a semiautomatic GTAW hot wire welding system technically known as High Deposition Metal Transfer Gas Tungsten-Arc Welding (HDMTGTAW), combined with stainless steel flux cored wire (AWS/ASME A/SFA-5.22 and A/SFA-5.22M) and argon shielding that is capable of producing quality welds with high integrity.

Experience with 800HT coker furnace tubes


Nathaniel Griffen, Phillips 66

Coker furnace tube failures in delayed coking units at refineries can have a major impact on safety and reliability. Alloy 800HT coker furnace tubes experienced higher than expected corrosion rates resulting in multiple failures. Metallurgical evaluations were performed and damage mechanisms were determined to be Nickel-Nickel Sulfide eutectic melting and sulfidation. The sensitization of alloy 800HT during fabrication and maintenance activities increased the susceptibility to sulfidation. Other possible damage mechanisms, such as carburization, creep, and naphthenic acid corrosion, were not key factors in the furnace tube degradation. The target audience for this presentation is engineers and experienced inspectors.

304 H stainless Steel Heavy-Wall Piping: Metallurgical and Design Considerations


Roxanna Alvarez, Lloyd's Register Energy Americas, Inc.

Welds of large diameter and heavy wall stainless steel (304H) piping, subject at service temperatures above 1000F, are prompt to crack after long time of exposure. Welds are expected to have the greatest susceptibility to crack at high stressed locations during shutting down, and starting up where Sigma phase formation along with creep damage would play a key role on susceptibility of cracking. Metallurgical and design control needs to be defined In order to reduce the likelihood of cracking. Filler metal and weld procedure should be carefully selected to minimized sigma phase. Welded elbows should follow the ASME requirements for fabrication. Chemicals composition control and annealing heat treatment would also contribute to reduce the probability of failure.

Managing Ammonium Bisulfide Corrosion and IOW Implementation


Michael Cayard, Flint Hills Resources LC

Hydroprocessing and hydrocracking units utilize a combination of pressure, heat, catalyst and hydrogen to remove undesired sulfur and nitrogen from the feedstocks. The corrosiveness of ammonium bisulfide solutions which form downstream of the reactors depends on a wide range of variables including, NH4HS concentration, H2S partial pressure, temperature and shear stress acting on the pipe wall, to name a few. This paper is intended to educate engineers and inspectors on the variables affecting the corrosivity and provide one users approach to managing this corrosion mechanism. Topics covered include: process assumptions used to provide data inputs into an NH4HS corrosion model, use of the predicted data to prioritize on-stream inspection, use of infrared scanning to monitor operational health, and selection of integrity operating windows.

Case Studies: Soda Ash Related Wash Piping Failures in Hydrotreaters


Jim McVay, Andeavor

Two case studies of failures of small bore connections in hydrotreating unit reactor effluent austenitic stainless steel piping systems where standard soda ash washing practices where utilized will be presented. In both cases the piping design called for use of forged fittings and Alloy 825 pipe nipples where failures occurred. Good practices for protection of austenitic stainless steel piping subject to Polythionic Acid Stress corrosion cracking (PTASCC) and avoidance of such failures will also be reviewed.

Damage mechanisms in old Mn-Mo vessels


David Moore, Becht Engineering

A Hydrotreater hot high-pressure separator and Catalytic Reformer reactors made of SA-302 Gr B Mn-Mo steel were inspected with sensitive PAUT techniques after many years in service. Many crack-like linear indications of various sizes were detected at welds and HAZ, including large indications at nozzle attachment welds. Weld samples were removed from both types of vessels to investigate the indications and help determine damage mechanisms and repair plans. Fitness-for-service was also performed and vessels were returned to service after successful repairs. This presentation will review most probable and credible damage mechanisms related to Mn-Mo steel after prolonged exposure to high temperature H2 charging conditions, including repair challenges and future integrity management strategies.

Union Oil Romeoville 1984 Amine Absorber Failure Revisited


Jeremy Staats, Becht Engineering

Almost 35 years ago the Union Oil Romeoville experienced a catastrophic failure of an amine absorber. The failure was due to SSC/SOHIC and determined the course of the US refining industry in focusing on wet H2S cracking issues over the next 4 decades. Given the installed base of sour service equipment, there have been very few leaks of PEI due to wet H2S cracking. The premise of this talk is that the industry has spent countless resources finding minor cracking and then having to deal with it and that we may have gone a bit too far. CCD and RBI programs conservatively list wet H2S cracking of vessels and that drives frequent inspections and repairs. This talk advocates using highly experienced materials/corrosion engineers to identify the few truly high risk equipment (amine absorbers, cold high pressure separators, FCC de-ethanizers etc. and then use them as a canary to indicate potential hydrogen charging issues in the unit and utilize IOW’s to keep out of operating ranges where severe damage can be expected. Other equipment would only be targeted for inspection when the canaries sing or with ISI. In a perfect world where inspection budgets were unlimited, one could say that this approach may be cavalier, but piping issues like CUI and localized corrosion are a much bigger real threat to integrity and people expend limited resources on inspecting wet H2S equipment that really does not lower the real risk of a leak (not damage).

Almost 35 years ago the Union Oil Romeoville experienced a catastrophic failure of an amine absorber. The failure was due to SSC/SOHIC and determined the course of the US refining industry in focusing on wet H2S cracking issues over the next 4 decades. Given the installed base of sour service equipment, there have been very few leaks of PEI due to wet H2S cracking. The premise of this talk is that the industry has spent countless resources finding minor cracking and then having to deal with it and that we may have gone a bit too far. CCD and RBI programs conservatively list wet H2S cracking of vessels and that drives frequent inspections and repairs. This talk advocates using highly experienced materials/corrosion engineers to identify the few truly high risk equipment (amine absorbers, cold high pressure separators, FCC de-ethanizers etc. and then use them as a canary to indicate potential hydrogen charging issues in the unit and utilize IOW’s to keep out of operating ranges where severe damage can be expected. Other equipment would only be targeted for inspection when the canaries sing or with ISI. In a perfect world where inspection budgets were unlimited, one could say that this approach may be cavalier, but piping issues like CUI and localized corrosion are a much bigger real threat to integrity and people expend limited resources on inspecting wet H2S equipment that really does not lower the real risk of a leak (not damage).

When is Hydrogen Bakeout necessary?


Marc McConnell, Pro-Surve Technical Services

A bake-out is used to drive hydrogen out of the steel, as trapped hydrogen can cause cracking in the weld. Typically the need to perform a hydrogen bake out happens during a maintenance turnaround, so the need for the bake out is frequently challenged in an effort to try and save time (cost).

The time and temperature needed to bake out the hydrogen to a level for a successful weld repair is controversial due to many fact based reasons, and when discussing with metallurgists or corrosion engineers, you will find degrees of opinion ranging from none to some. There are rules-of-thumb and/or “in-house” recommendations for weld inspection delays between 16 to 48 hours in various standards, but there is no firm basis for times.

Using Advanced Analysis to Reduce Hydrogen Bakeout Times


Scott Bouse, WJE Associates

Many companies in the Process Industries know that Hydrogen Bakeout is necessary before welding or grinding on carbon steels in sour service. However, few companies have a scientific basis for the required bakeout procedure, and instead rely on prior experience or guesswork to establish a bakeout plan. Even then, most references are intended to ensure a successful full-penetration weld repair, and do not account for actions that only influence the surface of a component.

This presentation will cover some of the analytic approaches available to owner-operators, including shortening bakeout times when repair activities are local to one surface, or in areas such as flanges where the thinner nozzle neck serves as a ‘choke point’ preventing hydrogen diffusion from a heavier section.

Comprehensive Refining Piping CML Optimization Review Process


Jim McVay, Andeavor

This presentation will be a follow-up to the presentation offered at the 2017 Inspection Summit as Andeavor now culminates a comprehensive review exercise for all common refining processes and implements a comprehensive program to optimize piping inspection program based on learnings. Learnings from initial implementation efforts along with developed tools helpful for implementation will be discussed. Useful learnings and special practices as they relate to specific processes and applications will also be discussed in some detail. It is expected that much of the information derived from the piping CML review exercise will be available in the public domain through API, likely some before the Inspection Summit. Access and best use of this public information will be discussed.

Corrosion Studies – Pitfalls and Some Good Practices


Jim McVay, Andeavor

Comprehensive corrosion studies, also known as degradation mechanism reviews, are now relatively common exercises in operating facilities, necessary for sufficiently technically well-grounded and dynamic inspection programs needed in today’s operating environments. While the newly issued API RP 970 (Corrosion Control Documents) provides guidance on the basic elements of corrosion studies, the document has omissions in many areas in which responsible operators need to address. Standardized criteria for consistent determinations of vulnerability (or lack thereof) to environmental cracking mechanisms, required rigor of review and analyses of process data inputs are but a few examples. This presentation will discuss experienced and possible pitfalls of in the execution of Corrosion studies and outline possible controls and practices to optimize the effectiveness of these efforts for their intended applications.

Corrosion Resistance of Ni-Co Electroplating on Bolting for Upstream/Downstream Applications


Omar Rosas, Doxsteel Fasteners

A common problem for fasteners in the oil and gas industry is the corrosion compromising their functionality and increasing the risk of failures. Coatings have been used to protect bolting from corrosion, nickel-cobalt electroplating provides high corrosion resistance to steel fasteners and enhances the assembly by preventing oversizing of bolts and nuts. In this work, the corrosion resistance performance of different coatings was compared; the superior performance of Ni-Co electroplating features this coating as a protection for carbon and high-strength steel bolts used in the Oil and Gas industry. The results from this effort are relevant for engineers, inspectors, and maintenance personnel in all sectors, from offshore and subsea equipment in upstream, to transportation and processing and refining in midstream and downstream.

Terminology Standardization in the Energy Industry and Corporate Guidance


John Bringas, Codes and Standards Training Institute (CASTI)

Standard terminology is a critical fundamental of all codes and standards, because without it, goo standardization cannot happen. For example, ASTM, ASME, ASM, AWS, ISO, GB, JIS, etc., handle terminology standardization differently, either by peer-reviewed balloted consensus or non-peer reviewed without consensus. Effective standard terminology requires minimal interpretation and must be used consistently. However, the same term may legitimately be used in multiple industries or circumstances where it has different meanings. Also, technology advancements require constant review of existing terms, adding new terms, and deleting old terms. This presentation will include corporate considerations that should be given to technical terminology used in codes and standards and how best to apply standard terminology within their internal specifications, 3rd party contractor specifications, purchase orders, and similar documents.

Proposed Updates to ASME B31.3 PWHT and Minimum Temperature Requirements


Phillip Prueter, The Equity Engineering Group, Inc.

The 2014 Edition of ASME B31.3, Process Piping, introduced substantial changes to PWHT requirements for P-No. 1 carbon steel materials. Specifically, PWHT is no longer a mandatory requirement (for any wall thickness). Fracture mechanics indicates the lack of a mandatory PWHT requirement for P-No. 1 components generally increases the risk for brittle fracture due to considerable weld residual stresses in as-welded components. Furthermore, recent work has shown the benefits of PWHT often outweigh the potential for decreasing fracture toughness. Given the industry concern regarding potential brittle fracture failures, proposed updates to the ASME B31.3 PWHT and minimum temperature requirements are offered based on modern fracture mechanics. This suggested guidance is consistent with the new Part 3 in the 2019 Edition of API 579-1/ASME FFS-1, Fitness-For-Service.

Case Study Comparison of Brittle Fracture Evaluation Methods for Flanges


Brian Macejko, The Equity Engineering Group, Inc.

ASME and API provide rules for establishing the Minimum Allowable Temperature (MAT) for carbon steel bolted flanges utilized in construction of pressure vessels and piping systems. Results can vary significantly depending on the Code being used to perform the evaluation. This presentation will summarize results from an extensive case study comparison between various design and post-construction standards. The case study will also include results obtained by using the recently proposed modifications to Part 3 of API 579-1/ASME FFS-1. Lastly, a Finite Element Analysis and detailed fracture mechanics evaluation will be performed for comparison to the various Code closed-form calculation procedures and to demonstrate the impact of material toughness variability on flaw sensitivity.

Seismic Loading of Aboveground Storage Tanks: Design and Fitness-For-Service Considerations


Phillip Prueter, The Equity Engineering Group, Inc.

Evaluating the behavior of large aboveground storage tanks (ASTs) during an earthquake is complex. Foundation-structure and fluid-structure interaction effects can influence tank behavior and failure modes. Furthermore, foundation settlement and shell distortion can diminish damage tolerance. Local stresses at anchor attachments and shell-to-floor junctions can be difficult to quantify without detailed analysis. Additionally, performing explicit dynamic analysis with liquid sloshing effects can be time consuming, expensive, and impractical. The intent of this presentation is to summarize simplified techniques to evaluate ASTs subject seismic loading and to compare case study results to detailed computational analysis. Additionally, guidance is offered to quantify the risk associated with operating potentially under-designed vintage ASTs. These simplified and advanced evaluation techniques can influence life-cycle management decisions and inspection strategies for ASTs.

Reliability of Nondestructive Testing Data for Fitness-for-Service Assessments


Nicolas, Obando, ABSG Consulting Inc.

FFS assessments are based on information collected from nondestructive testing (NDT) methods applied to the flaw/damage being evaluated. Hence, the reliability of the NDT data becomes a key factor affecting the quality of FFS assessments. A frequently used quantitative measure of the capability of an NDT method is the probability of detection (POD) which provides the probability of detecting flaws of various sizes under different inspection conditions. Knowledge of the POD can aide FFS engineers in evaluating NDT method capability and thus, the reliability of NDT data rendered. This presentation provides information on the NDT task group recently formed by API 579-1/ASME FFS-1 committee members to evaluate the reliability of NDT data and its effect on FFS assessments.

Predicting Dissimilar Metal Weld Failures Using Machine Learning Techniques


Martin Gascon, Intertek

The increasing share of renewable energy production has resulted in new challenges for the operators of traditional power plants who are required to maintain high reliability and high profits. For example, operations must become flexible when dealing with the thermal strain and the wear-and-tear of operations. This is not unlike the challenges found in the petroleum refining industry. This study found a correlation between flexible operations and Dissimilar Metal Welds (DMW) failures. We tested different machine learning techniques and found that artificial neural networks is the best approach for analyzing these type of failures, exhibiting an overall prediction rate over 90%. This method can even reasonably estimate the time to failure.

Pressure Safety Valve Integrity Management Using Risk and Reliability Method


Steve Matthews, Petrofac

An integrated risk and reliability methodology is described that enables focused, cost-effective management of PSVs and enhanced knowledge of PSV performance during operations. A case study, comprising a population of just under 400 PSVs, has demonstrated improvements in PSV risk management since 2009. A key objective of the methodology was to provide a robust, conservative approach for consideration by the local regulatory body, demonstrating that test intervals for PSVs could be safely extended, based on operation, testing and performance assessment. It has enabled year-on-year cost savings allocated to the PSV inventory, spares, transportation, and testing, combined with measurable improvements in PSV risk and reliability performance. It has also enabled appropriate focus on ‘bad actors’, non-critical, PSV performance issues that are often ignored during normal operations.

Developing and Sustaining Future Mechanical Integrity Specialists/Leaders


Clay Rodery, C&S Technology LLC

As operating companies lose their experienced specialists through retirement or other means of attrition, the challenge becomes developing and sustaining competent, technical/business savvy individuals to step in and continue to contribute effectively. For younger practitioners, it is a unique opportunity for those who choose to seize it. The presenter will offer insights from his 37-year career as possible tips to aspiring specialists, including: how to be more effective, good technical/communication/behavioral skills to develop, interview tips, and other qualities to enhance their personal and professional value. It will also give insights to managers on what to seek in a specialist, including rewarding and retaining those that they find. The presentation is targeted to engineers but could have applicability to managers and inspectors.

Introduction to Proposed Rewrite of API 579 Part 3 Procedures


Brian Macejko, The Equity Engineering Group, Inc.

Inconsistencies and inadequacies exist in the current brittle fracture screening procedures in the 2016 edition of API 579-1/ASME FFS-1. Results from an evaluation completed using the current published guidance may prove to be unsafe in some instances. The ASME/API Joint Committee on Fitness-For-Service (FFS) recently initiated a project to rewrite API 579 Part 3, Assessment of Existing Equipment for Brittle Fracture. The intent is to establish new Level 1 and Level 2 evaluation procedures and acceptance criteria developed using state-of-the-art fracture mechanics consistent with the Part 9 Failure Assessment Diagram (FAD) approach currently employed in Level 3 evaluations. In this presentation, the recently proposed procedures will be introduced, limitations and applicability will be discussed, and several case study examples will be demonstrated.

The Dow Chemical Robotic Platform Initiative


Twain Pigott, The Dow Chemical Company

The Dow Robotic Platform Initiative deploys the latest mobile and remote operated technology into the manufacturing facilities for inspection and maintenance activities to drive safety improvements and operational excellence in maintenance. Through the Dow Robotic Platform Initiative, Dow targets the elimination of Confined Space Entries for Inspection and Maintenance. As confined space entries are one of the most hazardous activities that occur in the manufacturing environment; Robotic inspections can eliminate potential hazardous conditions to employees and return the facility to production in much shorter times. This speech will cover Dow Vision and Strategy of how Robotics are being utilized currently and the future of Robotics in this space.

Omnidirectional Magnetostrictive Transducer for Guided Wave Testing of Large Shells


Sergey Vinogradov, Southwest Research Institute

Application of helical pass guided waves for the testing of large cylindrical shells/pipes has been investigated recently due to their ability to find corrosion in remote and hidden areas. This work describes a plate-application magnetostrictive transducer (MsT) with known characteristics which was incorporated into an automated omnidirectional scanner. This scanner rotates the directed MsT for data collection at regular intervals. Coupling of the transducer to the shell is accomplished using shear wave couplant. Received array of data is used for compiling B-scans and also for imaging utilizing a synthetic aperture focusing algorithm (SAFT). Performance of this new scanner in application to guided wave screening of large cylindrical shells, pipe supports and elbows will be discussed together with potential future directions in technology development. .

RBI Pitfalls and Best Practices


Mark Harmody, The Equity Engineering Group, Inc.

After implementing and reassessing hundreds of process units in upstream, midstream, and mostly downstream, we have witnessed what works and what doesn't. This presentation will focus on best practices, general tips, and pitfalls for beginning an RBI program, maintaining it, and reassessing the analyses in the future. Citing real world examples, this presentation will emphasize the importance of initiating a pilot RBI assessment, selling it to management, documenting the process, insisting on high data quality, choosing RBI methodologies, timing the implementations, moving from a time-based to a risk-based program, updating after inspection, planning for reassessments, and quantifying the benefits of RBI.

Career Progression - Paths, Milestones, and Timelines


Frances Dannenbrink, PinnacleART

A misguided definition of success hinges on pay grades, titles, and (limited) perspective. Success would be better defined as setting and achieving goals. The first step in defining those goals is reviewing the career options, and the steps typically taken reach those milestones. We will explore the culmination of experiences that not only qualify an individual for a role, but also ensure their readiness to take on the responsibilities. Finally, a review of the advantages and compromises between typical career paths will include: technical vs. leadership, advanced/specialty NDE vs. API visual, and contractor vs. owner/user roles. This subject matter is directed towards and will most benefit undecided or stagnated employees, and their supervisors.

The Inspection of Thermal Insulation & CUI


Ron King, National Insulation Association

The impact of corrosion under insulation (CUI) is well known. But what if the insulation system was installed and maintained properly – would that reduce the number of CUI occurrences? A thermal – mechanical insulation inspection program may help achieve that goal. There is general consensus that: Mechanical insulation knowledge base is slowly dwindling; Insulation “systems” are getting more complex; The shortage of experience and “qualified” workers continues to be problematic, The presentation will explore the potential impact a thermal insulation inspection program would have on reducing CUI and how it would positively impact the new construction, retrofit and the maintenance segments.

UAV-sourced integrity information becomes part of the O&G digital revolution


Jenny Adams, Cyberhawk Innovations

Drones can collect a massive amount of data – close visual inspections of specific areas through to a complete visual record of an entire asset. Digitising this data, i.e. presenting it as a 3D model or an inspection report hosted in the cloud, allows asset managers to make efficient decisions on the condition of their equipment, and prioritise/budget contact NDT and repair. Temporal analysis can be developed and defects tracked, leading to the prediction of future problems. Inspection engineers/asset managers will hear Cyberhawk discuss how operators are integrating visual data into digital asset management systems to support more efficient decision-making and better communication between operators and contractors, by utilising a single “shared truth”. The efficiencies and benefits gained by doing so will also be discussed.

Moving Ultrasonic Data without Cabling


Mike Wechsler, Mistras Group, Inc.

Our ability to transfer data from one medium to another has skyrocketed in the last several years, from FTP sites, to wireless, to the cloud. Every year things are getting faster and more efficient, allowing us the potential to now move ultrasonic data more efficiently. This presentation will discuss a project in which encoded ultrasonic data from a Phased Array system and scanner was transferred to a computer/analyzing station without cabling.

Corrosion Under Insulation: A Proactive vs Reactive Approach


Brittany Kopech, PinnacleART

Studies have shown that corrosion under insulation (CUI) is a $300 billion global problem. During the presentation, attendees will explore factors contributing to CUI that are often undocumented and review a suggested CUI inspection report template. CUI awareness has increased significantly in recent years however, many maintenance departments still struggle with justifying a budget for a CUI preventative maintenance program. Building an effective CUI inspection strategy relies on accurate data and this data is often missing from inspection reports and data management systems. An effective CUI inspection report template is a cost-effective way to collect important data effecting CUI susceptibility analysis and prioritization to better focus maintenance dollars. Following the presentation, attendees will walk away with a better understanding to identify factors contributing to CUI.

Baseline Heat Exchanger Inspections to Reduce Costs and Unscheduled Downtime


Timothy Rush, Mistras Group, Inc.

Mechanical damage and manufacturing defects can make their way from the manufacturing mills to shops and from the shops into heat exchanger bundles. The importance of baseline inspections provides cost savings up front vs. the costs incurred during operations due to unexpected failures, unscheduled down time, and safety. Performing baseline inspections on exchangers helps to ensure the tubes are free from I.D. or O.D. defects caused by mechanical or manufacturing defects that would affect the integrity of the tube performance. This presentation will discuss the importance of performing baseline inspections and the protocol to follow during heat exchanger examinations.

Improve Thickness Survey Data Management Using Connected, Cloud Enabled Instruments


Dianne Hillhouse, Olympus Corporation of Americas

Development of connected ultrasonic inspection instruments, along with mobile applications, and Cloud based software solutions are enabling rapid efficiency gains in the management of data collected during corrosion thickness surveys. Real-time transfer of thickness data from inspection device to applications via the internet allow for rapid data analysis and reporting, easy access to progress in inspection tasks, and substantial reduction or elimination of manual data processing. The efficiency gains in data management enabled by these technologies allow for more measurement points per inspector per day, reduction in errors that can be introduced with manual processes, and continuous provisioning of new inspection points to the instrument and operator as sections of the overall job are completed and data is pushed to the Cloud or mobile application.

Automated Radiography of In-Service Piping


John Musgrave, Mistras Group, Inc.

The use of automated radiography, for both the detection of corrosion under insulation (CUI) and the presence of internal pitting, has been developed and refined over the last decade in the Alaska upstream environment. With advancements in the technology, the methods used in the upstream environment are now applicable in the midstream and downstream segments of the industry. In specific applications, this automated technique is 20 times as productive as the corresponding manual techniques.

Inspection process: The "What", "When", "Who" and "How"


Tony Poulassichidis, Anadarko Corporation

The presentation provides an inspection process overview for fixed equipment and identifies the four main inspection process questions that are required for success: the “What”, “When”, “How” and “Who”.

Case studies based on gas plant facilities work are presented to describe the corrosion mechanisms review and determining inspection intervals.

Discussion is further focused on presenting advantages and disadvantages for setting inspection intervals based on a) time criteria, b) risk based inspection and c) a hybrid approach that is grounded on time criteria and mainly focused on likelihood-of failure analysis.

Corrosion Blisters & Blooms Evaluation - Pulsed Eddy Current Testing


John Ferguson, Mistras Group, Inc.

Several environmental components contribute to areas of corrosion in piping. These conditions often result in corrosion blisters/blooms. These corrosion blisters/blooms can cause complications when attempting to accurately size the remaining wall thickness of these areas without removal. A solution for these obstacles is to perform Pulsed Eddy Current Testing (PECT). This application is an electromagnetic technique that is used in detecting wall loss in ferrous materials under layers of coating, fireproofing, or insulation. This technique has recently been performed to measure estimated wall thickness under corrosion blisters/blooms through direct contact. This presentation will detail these examinations and the path moving forward to safely and effectively determine the remaining wall thickness of this type of defect mechanism.

Non-Destructive-Based Asset Management Techniques for High-Pressure LDPE Equipment


Chris Tipple, Structural Integrity Associates

Low density polyethylene (LDPE) assets, particularly operating in the high-pressure regime, pose series of challenges unique to high-pressure assets. Some of these challenges include access restrictions, small diameter deep bores, thick sections, weld overlays, complex geometries, and small crack size thresholds. To address these challenges, advanced surface-based (Eddy Current Array) and volumetric (Phased Array Ultrasonic and Guided Wave Testing) non-destructive examination (NDE) techniques are used to compliment Fitness-for-Service evaluation protocols. Applying these modern techniques in new designs, and updating of in-service inspection plans for this high-pressure equipment can lead to a more accurate assessment of the equipment’s Fitness-for-Service, reduced maintenance costs, proper asset management of key capital equipment, and reduced turn-around time.

Ultrasonic Applications Engineering Using Phased Array


Bruce Pellegrino, Sensor Networks, Inc.

Ultrasonic applications can be successfully developed, solved or optimized with either standard "off-the-shelf" or custom-designed and fabricated Phased-Array Ultrasonic (PAUT) transducers. In either case, a process should be followed in order to enable and/or optimize a validated technique. This paper will outline the many steps in the process of PAUT applications engineering and show several case histories of such developments which cover a wide range of plant components.

Dead Leg Inspection Management Systems


Eric Onya, SNEPCo

Deadlegs by definition, present an unpredictable failure mode to the Asset Integrity and Inspection Engineers because of their peculiar flow regimes, thereby making them of Interest for a more focused inspection program, most especially for hazardous services.

This presentation aims at developing a detailed management process for deadlegs in the Oil and Energy Industry, beginning with its identification, Risk assessment, Workscope and Work Pack Generation, Identification of suitable NDE technique(s), Inspection Execution, Review of Inspection results in conjunction with Corrosion Engineers, and planning of subsequent inspection intervals.

It is expected that a full implementation of the recommendations of this management process will bring about an overall reduction in recorded incidents of Loss of Primary Containment (LOPC) in the Oil, Gas and Chemical Industries.

On Stream Corrosion Monitoring for Industrial Processing Piping


Sam Ternowchek, Mistras Group, Inc.

Implementing a comprehensive corrosion monitoring program for industrial processing piping involves the use of several monitoring technologies. Two key items of information for a monitoring system are how corrosive is the material flowing though the piping and what effect is it having on the piping. Described in this presentation is an on-stream monitoring system that utilizes a new insertion style probe that is based on material loss as a measurement of the corrosiveness of the process material. It also incorporates permanent ultrasonic thickness transducers attached to the piping in key areas. Data is transferred via a wireless HART network for processing. The data can be displayed locally vis DCS or remotely via a web page.

Remote Acoustic Emission Monitoring of Critical Fixed Equipment


Steven Garcia, Ameriscan LLC

Acoustic Emission (AE) testing is an NDE method which can be used to complement current structural health monitoring solutions. Using acoustic emission equipment, the condition of critical structures can be monitored in real-time without destroying the material condition or disrupting normal operations. Plant parameters can also be correlated to AE data to understand source behavior. Additionally, significant cost savings can be realized because AE monitoring does not require thermal insulation removal.

Long-term monitoring projects spanning from several days to several years have been successfully implemented using this methodology.

The methodology and lessons learned performing such long-term, real-time inspections using acoustic emission is the topic for discussion.

Mobile/Digital Inspection & Testing for Mechanical Integrity Programs


Russ Davis, Mistras Group, Inc.

Traditional MI field inspections and testing have been paper-based. Technological advances now are contributing to the quality and efficiency of the field MI program. This presentation will discuss how advances in inspection and testing data gathering and reporting are leading to better quality and efficiency. The mobile devices allow almost real-time engineering analysis and field data gathering. This presentation will also discuss how data analysis is contributing to more predictive MI programs. Currently huge amount of data can be collected and predictive analytics can be utilized for better life assessments of critical equipment. Mobile field technology is contributing to both data gathering and data analysis to increase program efficiencies and minimize wasted time and resources.

Increasing Uptime and Plant Reliability by Deploying Asset Monitoring Solutions


Arturo Nunez, Mistras Group, Inc.

Traditionally, periodical testing of assets has been the method of choice to evaluate their integrity. This approach can have some disadvantages such as erroneous measurements, unavailability of the asset for testing or testing using different instrumentation settings/techniques. The development of instrumentation for continuous monitoring allows the inspection intervals to be reduced significantly as well as to be able to monitor the asset during the very different operating conditions it experiences, hence allowing to identify correlation between fault mechanisms (cracks, leaks, corrosion, arcing, etc.) and the operation of the asset.

This paper presents different applications where asset monitoring is used for detecting active faults in power transformers, tube leaks in boilers, cracks on combustion turbines, and thickness measurements. Case studies where of monitoring benefits are presented.

The Potential Roles of Permanently Installed NDT Sensors


John Nyholt, John Nyholt Consulting, LLC

Permanently installed monitoring (PIM) NDT sensors have been commercially available since the 1990's. Many new PIM sensor manufacturers and technologies have since entered the market, however many petrochemical facilities still have limited or no experience with these technologies or their benefits. This talk will overview the various NDT technologies that are now available as a permanent, semi-permanent, or in-motion PIMs application, damage mechanisms that can be monitored by PIMs and how an integrity management program could benefit from highly reliable NDT data on demand. Several real world case studies will be presented followed by a recommendation for potential API PIMS Guidance on Practice document.

Handheld Analyzer for Carbon, CE Determination in Pipeline, Refinery Materials


Don Sackett, SciAps, Inc.

A handheld technology is presented for in-field analysis of carbon content and carbon equivalents in steels and stainless. The method is now acknowledged by API RP 578, Third Edition. The device uses laser-induced breakdown spectroscopy (LIBS) – an established laboratory technique now miniaturized. LIBS fires a pulsed laser to vaporize the material to form a plasma. The plasma cools, the electrons recombine with the atoms, and emit characteristic light in the UV, visible and infra-red. A spectrometer measures the light at various wavelengths to measure concentrations of C, Si, Al, Cr, Ni, Mo, Cu, V, Nb, Ti, Mn, W, Pb and other elements, and calculates carbon equivalents. Selected results, test methods and PMI best practices learned from 250 installations worldwide will be presented.

Phased Array Assisted Analysis Software for Weld Inspections


Nicholas Bublitz, VeriPhase, Inc.

Phased Array is a valuable inspection technique for welds as an alternative to conventional UT methods or radiography. Large amounts of Phased Array encoded data can be collected quickly, but analysis and reporting usually take significantly longer. The analysis process can be considerably expedited by utilizing assisted analysis software that identifies indications while also providing additional analysis tools for quick final disposition of the software generated results. Data quality issues like data dropout and loss of couplant can also be reported automatically, ensuring high quality and code compliant data. Real world case studies will be presented highlighting the benefits of utilizing software for encoded Phased Array weld inspections.

Non-Intrusive Inspection (NII) of Pressure Vessels


Jonathan Burns, Mistras Group, Inc.

Pressure equipment has traditionally called for internal visual inspections augmented with applicable non-destructive evaluation (NDE) to evaluate a pressure vessel’s suitability for continued service. This burden is expensive and inherently unsafe. Recent internationally recognized and generally acceptable good engineering practice (RAGAGEP) makes allowances for non-intrusive inspections (NII) when the external NDE provides data which is as good as, or better than that provided by an internal inspection. The advancements in NDE technology now enable the user to extract detailed information relating to the integrity of the pressure vessel, which in many cases is better than that which can be obtained by an internal visual inspection; it also provides a much safer alternative. This presentation will outline how to implement an NII program.

Chevron NDE Performance Demonstration Qualification Testing


Michael Sens, Chevron

This presentation will cover Chevron's 30 years of experience in non-destructive testing performance demonstration qualification of technicians. Topics covered in this presentation will span the history of the program, methods covered in the program, statistical data and observations of results, as well as the future of the program with further developments and how they will affect the industry.

A Wireless, Battery Free Permanently Installed Ultrasonic Sensor


Chenghuan Zhong, Inductosense

Manual ultrasonic testing for material thickness can often result in erroneous data that can frustrate and hinder the inspection effectiveness of an ultrasonic corrosion monitoring program. Permanently installed ultrasonic sensors provide a more reliable and repeatable thickness measurement for measuring and trending material damage mechanisms. Long term, nearly error-free data trending of inherent and service-induced material flaws may also provide confidence in flaw characterization by consistent and stabile ultrasonic measurements. However the installation, wiring and wireless communication requirements of a large scale permanently installed sensor can be cost prohibitive. This presentation discusses a wireless, battery-free permanently installed ultrasonic sensor that is 1/32 inch (0.79 mm) thick and can be installed beneath coatings or insulations without use of wires, wireless gateways or plug and play instrumentation.

Review of Applications Using Updated FMC/TFM Methods


Leon Barton, The Phased Array Company

The Total-Focusing-Method family of ultrasonic imaging techniques, such as SAFT, TFM, and AFM, are becoming increasingly industrialized and available for field applications. These techniques offer many benefits over conventional Phased Array UT; superior resolution, an overall improved ability to qualify and quantify defects, surprising simplicity of setups, and in some cases, breaking of attenuation and scattering noise. This paper proposes to review at an early stage, a range of applications using TFM techniques utilizing relatively low cost instruments, as well as state of the art solutions to complex inspection applications. Some of the applications to be discussed will be; girth weld inspection, composite inspection (specifically CFRP), as well as detection of traditionally challenging damage mechanisms such as HIC (Hydrogen Induced Cracking) and Hydrogen Embrittlement.

The Ultimate Safety Moment


David Bajula, Acuren

Industrial and workplace safety are pretty much mainstream. What doesn’t always get talked about is the “quality” of work that is performed or the minimum quality level that is expected. The presentation will discuss how a unique harmony of training, knowledge and experience is paramount to the NDT inspection performance and bring attention to many human factors that are not always considered including a parallel with HEART and the sense of urgency for Honesty, Excellence, Accuracy, Respect and Teamwork, all of which is required to ensure that Ultimate Safety is achieved. Although the “Ultimate Safety Moment” was initially intended for our Level II technician population this will also benefit operational management, QA/QC personnel, audit personnel and general management.

Inspector Training Post Certification


Frances Dannenbrink, PinnacleART

The API certification examination is one of the most difficult exams that some of us will take in our lifetimes, but what comes next. Too often a clear path forward is not given and newly minted inspectors are sent forth to learn on their own and with limited guidance. By instituting a mentoring and training program, the learning curve can be greatly reduced, valuable knowledge from senior inspectors can be passed on to junior inspectors, and the overall quality and value of inspections can be greatly enhanced. API certification is not the end, it is only the beginning.

Benefits of Implementing an Appropriate Inspection Data Management System


Natalie McIntosh, Lloyd's Register

To effectively maintain reliability and safety for complex equipment and facilities, owners and operators do well to utilize effective tools to manage the life of their assets. Thus it is important to select the appropriate Inspection Data Management System (IDMS). This presentation aims to highlight the potential benefits that can be derived from the utilization of an appropriate IDMS to the inspection management strategy: Simplification of Daily activities; Compliance with Standards and Regulations; Performance of activities on schedule; Maintenance and easy access to inspection records while improving management reporting and trend analysis; Appropriate Gauge interface. The target audience for the presentation are Inspection Managers, Engineers and Inspectors.

Value Versus Cost: MI Quality Assurance/Quality Control Processes


Holley Baker, The Mistras Group, Inc.

This presentation will describe QA requirements for MI in the PSM rule, including impact on design, construction, installation, and maintenance from a value versus cost perspective. It reviews QA issues including missed design opportunities, fabrication defects, non-compliance to specifications, shipping damage, and improper installations. The industry can benefit from a better understanding of the regulatory view of QA. This presentation will provide valuable insight into proven QA programs and relationships to design, vendor qualification and surveillance, new installations and spare parts and will include recommendations for resolution. This presentation explores the boundaries of acceptable reliance on vendors and provides relevant information to management and field personnel. It explains the value of defining, establishing and maintaining appropriate practices necessary for the quality of critical assets.

Turnaround management - Maximizing MI Program Value during Shutdowns


John Bailey, Innovative Inspection Solutions

When production is stopped to perform a shutdown or facility turnaround, minimizing down time and maximizing productivity is absolutely critical. Compressing the shutdown schedule or avoiding delays on the plan execution critical path can lead to significant cost reduction and a quicker return to income generation. While wall chart hand written updates are simple to implement, they lack the robustness of web enabled access and reporting updates that can minimize slack time between activities to save thousands if not millions of dollars. Integrating turnaround management with the Mechanical integrity system not only expedites access to critical information, but it allows real time progress tracking and updates to the master project schedule.

Preview of API RP 588 – Source Inspection


Peter Hunt, Independent Consultant

API is working on a new SCIMI document covering what an inspector would require in order that they can competently conduct source inspection of new equipment. This presentation is to cover an overview of 588 which includes levels of training of which four distinct levels are identified. Source inspection activities include development of a management program, inspection performance and an extensive review of all pertinent design documents. It also will cover the tools and equipment needed, the various NDE techniques used and how a source inspector can accept that the equipment meets all quality requirements. The various manufacturing fabrication process are discussed along with discussion on construction of pressure vessels and piping. The presentation will review the contents of the new document.

Effects of Weld Type Variation on TFM Imaging Techniques


Coleman Flanagan, Olympus Scientific Solutions Americas

Ultrasonic examination of welded materials is widely used in industrial markets. Phased array technology created improvements to probability of detection and characterization of weld defects. More recently, total focusing method (TFM) imaging has shown enhanced defect resolution and improved geometric flaw representations, especially in the inspection of girth welds used in the construction of pipelines. Predominant ultrasonic approaches for girth welds require zonal discrimination techniques and include lengthy and tedious procedures. The advent of TFM instrumentation has fueled activities illustrating their potential efficiency and imaging value for girth weld inspection. These TFM techniques have been extended to other applications including construction welds. However, girth weld techniques do not necessarily transfer directly to other weld types. A comparison of TFM results on multiple weld configurations follows.

Inspection Coordination: Standardization for Improvement Source Inspections Performance


Ysolda Rujano, PREGO Energy Quality Consulting

The ITP is the reference for the critical stages of fabrication, inspection and testing; it establishes the applicable documents, the acceptance criteria, records and define the inspection points. An appropriate ITP could make the difference between a successful and a poor performance project. The importance of the ITP increases when the technical requirements, inspections and tests are beyond the standards, i.e., if the project has limitation for the carbon content on carbon steel plates, that are more strict than the standard material specification (ASTM, API), the review and approval of MTR’s before starting fabrication must be a rule. This presentation proposes a practical methodology for the standardization of the ITP and the inspection process, for those source inspections carried out through Third Parties.

Using Autonomous Drones for Ultrasonic Inspection of Flare Stacks Today


Jamie Branch, Apellix

Performing ultrasonic testing (UT) of flare stacks using autonomous drones offers an alternative and safer approach to obtaining wall thickness measurements. Autonomous flight describes the aircraft’s ability to programmatically approach and touch a standard UT probe to an elevated material surface without human interruption. This feature is critical for elevated structures, as the human eye has difficulty assuring proper alignment and contact while standing on the ground. Case studies will be presented to illustrate the current state of the technology. The benefits, and limitations, of autonomous UT drones will be evaluated and discussed in specific regards to flare stacks, as well as generally for elevated equipment and infrastructure.

Downloads:

Training Course Schedule

Sponsor & Exhibitor Prospectus

Exhibitor Floor Plan

Fax to 202-682-8222 

Application Deadlines

Sponsor/Exhibitor Applications and booth selection can be submitted according to the following acceptance windows:

2017 RETURNING SPONSORS
Up to 5:00 PM Eastern on Tuesday, July 31, 2018

NEW SPONSORS
Between 5:01 PM Eastern on Tuesday, July 31, 2018 and 5:00 PM Eastern on Tuesday, August 28, 2018

2017 RETURNING EXHIBITORS
Between 5:01 PM Eastern on Tuesday, August 28, 2018 and 5:00 PM Eastern on Tuesday, September 18, 2018

NEW EXHIBITORS
After 5:01 PM on Tuesday, September 18, 2018 (until the exhibit area sells out)

Please do not submit your application prior to the schedule above. If you submit your application before the above dates, your first choice may not be available.


Exhibitor Regulations

In adherence to the good neighbor policy, please note the following rules and regulations:
  • All promotional activities and distribution of literature must take place within the confines of the assigned booth. Distribution outside of the confines of the booth, including all API and Westin public areas is strictly prohibited.
  • If a booth noise level is particularly disturbing or disruptive, Show Management will direct that the noise be turned down. Booth activities deemed too disruptive may be discontinued at Show Management's discretion.
  • All speakers must face inward and not out towards the aisles or neighboring Exhibits. Exhibitors found in non-compliance, will be required to modify the direction of the speakers to a more suitable position.
  • A maximum height of eight feet is allowed only in the rear half of the booth space, with a four foot height restriction on all materials (product or equipment) in the front half of the booth. No booth element can impede the aisles. End-cap or 20x20 booths must not impeded line-of-sight above four feet to the front 5 feet of neighboring booth.
  • All booths should be designed in such a way so as to eliminate line of sight obstructions from one exhibit to the next.
  • Delivery or removal of any portion of an exhibit will not be permitted during exhibit hours.

Exhibitor Registration

Deadline for registering your additional staff: 5:00 PM EST, January 18, 2019. Please identify your exhibit staff early!

Each exhibiting company receives one full conference registration with the purchase of booth space. In addition, exhibiting companies may register up to three additional staff for the full conference at a discounted rate of $495 each. Discount codes will be provided to the “Main Contact” listed on your exhibitor application upon email confirmation of your booth assignment. If you have not received these codes, please contact registrar@api.org.

Platinum, Gold and Silver sponsors receive complimentary passes as identified in the Sponsorship and Exhibitor Prospectus, in addition to the 3 discounted registrations allotted with the booth.


Exhibit Hours

Tuesday, January 29 7:30 am - 6:30 pm
(with Opening Reception from 5:00 pm - 6:30 pm)
Wednesday, January 30 7:30 am - 5:00 pm
Thursday, January 31 7:30 am - 1:00 pm

Exhibitors are welcome to attend all sessions. API recommends an exhibitor representative be in their booth during the scheduled coffee breaks and receptions.


Exhibit Hall Set-Up and Tear Down 

Set Up
Monday, January 28
10:00 am - 6:00 pm
Tear Down
Thursday, January 31
1:00 pm - 6:00 pm

Exhibitor Order Forms

Each exhibit booth includes: 8' black drape behind booth, 3' black drape between booths, one 6' x 30" skirted exhibit table, Carpet (black, without padding), two side chairs, and one wastebasket. One (1) 120 volt electrical outlet will also be provided to each exhibit booth. Free wireless internet access is provided throughout the exhibit hall.

BoothSample

2019 Inspection Summit Booth Sample 

Exhibitor is responsible for ordering the following from Freeman:

  • AV 
  • Booth furniture
  • Plants
  • Etc.

Freeman Decorating Services Handbook - Available early December.

Order early to take advantage of advance order discount rates; Place your order by January 11, 2019.

You can order the same materials in the Decorating Services Handbook above using Freeman Online - Available Soon.

Freeman AV Order Form (Available Soon) - Note: One (1) 120 volt electrical outlet is provided for each exhibitor. 


Shipping Information

Exhibitors are highly encouraged to ship directly to Freeman. Shipping address details are found in the Freeman Handbook.

The convention center does not have a receiving dock open to accept packages prior to January 28. If shipping to the convention center instead of the recommended Freeman warehouse, your items can arrive at the convention center between 8:00 AM - 6:00 PM on Monday, January 28th. The convention center staff has notified us that in the past they have had several problems with vendors sending their items too early (when the building is closed). Subsequently, they get returned to the sender. If you like, shipping directly to your hotel is another option. If shipping to one of the 3 conference hotels, you are allowed 3 days prior to the day the group starts, however larger items (i.e. palates) need to ship directly to the convention center.

Exhibitor Floor Plan

Sponsors & Exhibitors Booth Number
Stronghold Inspection 104
Amerapex Corporation
105
Proceq USA 108
MFE Rentals 109
ABS Group
110
TesTex, Inc. 112
Eddyfi Technologies 113
CoreStar International Corp 115
Northern Inspection Services, LLC 118
ViewTech Borescopes 119
Consulting and Field Services, LLC 120
Available - Reserved for Sponsor 121
The Phased Array Company
205
Intertek 208
SciAps, Inc 209
Tulsa Inspection Resources 210
ASTM International 211
Ameriscan LLC 213
Pro-Surve Technical Services 214
PK Technology 215
Thermo Fisher Scientific 216
Spitfire Aerial Services 217
Sentinel Integrity Solutions 218
AsInt, Inc.
219
Curran International
221
Quest Integrity 304
Team Industrial 305
Provenance Consulting
308
IRed Thermal Group LTD 309
Fortress Oil & Gas, LLC 310
Advanced Corrosion Technologies & Training 311
QSA Global, Inc 312
MPM Products 313
OES Asset Integrity Management 315
ClampOn Inc. 316
FTH, LLC.
317
ALS
318
Lloyd's Register
319
Magnetec Inspection, Inc. 320
The Equity Engineering Group 405
JIREH Industries 408
NVI 409
Hocker, Inc. 410
Frontics America 411
NDT Seals, Inc. 412
Metegrity Inc. 413
Guided Wave Analysis LLC
414
Sonaspection 415
Ingu Solutions 416
doxsteel fasteners 417
Irisndt Inc. 418
Stress Engineering Services 419
Olympus America Inc. 505
Sensor Networks, Inc. 508
FlawTech America, LLC 509
Turner Specialty Services, LLC 510
Inspection Plug Strategies, LLC 511
Operation Sustainability, LLC 512
Becht Engineering Co. Inc 513
Danatronics
514
Speir Hunter North America
515
Metal Analysis Group 516
CodeWest 517
Premium Inspection & Testing 518
Acuren Industrial Services
519
Siemens 604
Versa Integrity Group 605
Access Plug Flange, Inc. 608
Mobideo 609
Lavender International NDT USA LLC 610
Dakota Ultrasonics 611
Structural Group 614
VMI 615
Guided Ultrasonic Ltd 618
G2 Integrated Solutions 616
Mistras Group, Inc. 619
Available - Reserved for Sponsor 620
Available - Reserved for Sponsor 701
Zetec 703
Sentry Equipment Corp 705
Zerust Oil & Gas 707
CTI Industries, Inc. 708
Sonomatic Inc. 709
DJA Inspection Services, Inc. 710
Gecko Robotics 712
PinnacleART 713
DÜRR NDT GmbH & Co. KG 714
Koch Specialty Plant Services 716
Ionix Advanced Technologies 717
Wood PLC 719

Platinum Sponsors

Conference AppEquity
Conference LanyardMistras
Luncheon Jan. 29 Siemens
Luncheon Jan. 30 Stronghold
Luncheon Jan. 31Stress
Conference BagTeam
Epic Pool PartyVersa
Opening ReceptionWood

Gold Sponsors

Continental Breakfast Jan. 29Magnetec
Continental Breakfast Jan. 30PremiumInspection
Continental Breakfast Jan. 31Intertek

Silver Sponsors

Mid-Morning Coffee Break: Jan. 29Quest
Mid-Morning Coffee Break: Jan. 30Lloyds
Mid-Morning Coffee Break: Jan. 31Sentinel
Mid-Afternoon Snack Break: Jan. 29Olympus
Speaker Breakfast: Jan. 29 - 31Auren
John Reynolds

Mountains We Have Climbed – Mountains We Still Need to Climb

My talk will be about FEMI Mountains we have climbed, i.e. the most significant fixed equipment mechanical integrity (FEMI) accomplishments we have made over the last few decades. But lest we get complacent there are FEMI mountains we still need to climb, i.e. the FEMI challenges we still need to overcome to further reduce FEMI incidents in our industry. In my younger, slimmer, fitter, more adventurous, more vigorous years of life (the summer years of my life), I was a mountain climber. I summited 32 mountains in the Rockies, the Cascades, the Canadian Coastal Range and Alaska. Climbing mountains was not easy for me, but it is exhilarating, breath-taking and provides a sense of accomplishment once you reach the summit. The view from the summit is always worth the climb. Mountain climbing gave me confidence in myself and taught me a lot about life, e.g. that I could achieve most anything that I set my mind to. It taught me that I could rely on myself and that I could go above and beyond what I thought I was capable of. It also taught me that if I was going to achieve even bigger things I would need to be a part of a like-minded team of climbers who all relied on each other to get safely up and down the mountain each time. Today I celebrate for the past 50 years having been a part of a like-minded team of FEMI mountain climbers whose goal is to continue to summit more FEMI mountains.

Today I find myself well beyond my physical mountain climbing days and deep into the winter of my FEMI career. There are not enough years left to do all the things I still want to do. So in my talk, I will celebrate the FEMI achievements we have collectively realized and encourage us all to set our sights on even more FEMI accomplishments. In my talk at this Summit I will summarize some of those FEMI summits that our team of mountain climbers has achieved and mention some of those FEMI mountains that we still need to conquer.


John Reynolds is a Principal Consultant with Intertek Asset Integrity Management, Inc. Prior to this he was a Master Engineering Consultant with Shell Oil's Westhollow Technology Center in Houston. After graduating from the University of Wisconsin with degrees in Mechanical and Metallurgical Engineering, John joined Shell in 1968 and retired from Shell in 2006. Over the 37+ years of employment with a number of the Shell companies, John held various engineering and management positions at Shell's refining and chemical processing sites, as well as central offices in the United States and Europe. Along the way, one of John's favorite activities was providing leadership for Shell's intranet communities of interest dealing with the 101 Essential Elements of Fixed Equipment Mechanical Integrity (FEMI). The focus of John's entire 50+ year career has been on establishing and improving FEMI programs in the petroleum and petrochemical industries. As part of that continuing goal, another of his favorite activities is continuing participation in the API/AFPM Process Safety Site Assessment Program (PSSAP) as one of the FEMI specialists providing feedback to operating sites that seek to improve their FEMI programs.

Since retiring from Shell, John has remained active in FEMI activities serving as an industry consultant and expert witness for numerous refining and petrochemical companies. He has been and is currently the master editor for several API Standards on Inspection and FEMI-related topics, and remains active in both the API Subcommittee on Inspection and Mechanical Integrity (SCIMI) and the ASME Post- Construction Committee (PCC). John is the past Chairman of the API Subcommittee on Inspection, the API Task Group on Inspection Codes, the API Task Group on NDE Technology, the API Task Group on API 580 RBI, and the API User Group on Risk-Based Inspection. He has also been the Downstream Business Sector Lead for the Planning Committee of the API Inspection Summit since its inception in 2007. Over the years, John has authored more than 90 articles and/or presentations on FEMI subjects, many of which have been published with Inspectioneering Journal and are summarized in his book "101 Essential Elements in a Pressure Equipment Integrity Management Program."

San Luis
5222 Seawall Boulevard
Galveston, Galveston Island, TX 77551
Call: 409-744-1500
Room Rate: $175, Mention API Group Rate
Reservation Deadline: December 31, 2018 or until room block is sold out

Hilton Galveston Island
5400 Seawall Boulevard
Galveston, Texas, 77551
Online Reservations - Available Soon
Call: 409-744-5000
Room Rate: $165, Mention API Group Rate
Reservation Deadline: December 31, 2018 or until room block is sold out

Holiday Inn
5002 Seawall Boulevard
Galveston, Texas, 77551
Online Reservations - Available Soon
Call: 409-740-3581
Room Rate: $145, Mention API Group Rate
Reservation Deadline: December 31, 2018 or until room block is sold out


Avoid Housing Scams

Note: API has not contracted with any third party for hotel arrangements and will not call or email you directly to make housing arrangements on your behalf.

Should you receive a call or email from a third-party provider, please collect as much information as you can and let us know immediately. “Room Poachers” have been known to act as representatives of API, or authorized providers of API, to offer room discounts or alternative accommodations to our attendees – often to the attendee’s detriment. These companies are not affiliated with API, and reservations made through these companies for our meeting cannot be guaranteed.

How It Works

This deceptive practice (called “room poaching”) is carried out by third‐party companies that act as travel agencies, wholesalers, or even API to solicit registrants for room reservations. The poacher might inform registrants that the hotel room block is “sold out,” and that if you do not book with them immediately, you may not get a room. Room poachers make it more difficult for us to meet our room block commitments, and expose us to penalties and increased room rates for our events. Room poachers often don’t deliver on promises to customers. When customers arrive, reservations are non‐existent or the hotels are not conveniently located. Sometimes the rooms have been cancelled and hefty cancellation fees have been placed on the customer’s credit card.

Don’t Be Deceived

If you are contacted by anyone asking if you need a room for the API Conference, please get as much information as you can (their name, company name, phone number, etc.) and pass it along to registrar@api.org. Always make your room reservation directly with the information provided by API or a trusted source.

API will use all legal means possible to prevent these groups from operating.

Please contact registrar@api.org with any questions.