Global Magazine - Oil & Gas Edition (Fall 2014)

SOFTWARECONSULTINGGEOSPATIALANALYSISDESIGN&DRAFTINGFIELDSERVICESRECORDSMANAGEMENTRECORDSMANAGEMENTFIELDSERVICESDESIGN&DRAFTINGGEOSPATIALANALYSISCONSULTINGSOFTWARE

DATA INTEGRITY

ATLAS: THE NEW MODEL STANDARDRecent advances in GIS and database technology have created the opportunity to view pipeline data management in a whole new light. PAGE 5

NEW CONSTRUCTION

THE MARCELLUS PLAY A look at Appalachia’s resurgence, new infrastructure, and how pipeline operators are managing the boom. PAGE 31

REGULATORY COMPLIANCE

3D FACILITY MODELS Driven by an increasingly stringent regulatory environment and increased data complexity, pipeline operators turn to 3D modeling. PAGE 13

SOLUTIONS FOR THE ENERGY INDUSTRY

glOBALMAGAZINE

FALL 2014

PRESIDENTFred Spickler

CHIEF TECHNOLOGY OFFICERTroy Walda

MANAGING PARTNERJohn Spangler

MARKETING COORDINATORDanielle Baxter

MANAGER OF HOUSTON OPERATIONS

Nicholas “Nick” Guerrero

MANAGER OF FIELD OPERATIONS

Brett A. Rape

DIRECTOR OF ATLANTA OPERATIONS

Eric Klein

SENIOR GIS CONSULTANTJoseph Howell

MANAGER OF GIS SERVICESPatrick Boes, GISP

CLASS/HCA PRODUCTS MANAGER

Tina Ivey

REGULATORY COMPLIANCE SPECIALIST

Mike White

APPLICATION DEVELOPMENT MANAGER

Patrick Johnson

CADD PROJECTS MANAGERSamir Buric

SENIOR GIS ANALYSTDavid Ellerbeck

SENIOR GIS APPLICATION DEVELOPER

Chris Goz

GLOBAL MAGAZINE HAS ARRIVED!

At Global Information Systems we believe it is our duty to provide our Energy Partners with a full range of expert solutions for collecting, integrating, and managing data. Our team combines software design, field technology, and geo-spatial analysis to bring you the latest and most innovative industry advancements.

Within these pages, you will find information on our basic products and services in addition to articles that handle topics from pipeline and facility maintenance to project management for new construction and the application of GIS technologies to some of the industry’s most urgent concerns. We consider this part of our commitment to a future for us all that is clean, safe, secure, and independent.

We hope you’ll enjoy reading Global Magazine’s Oil & Gas edition and learning about how we can partner with you to further your business goals and help move the industry forward.

The Official Magazine of Global Information Systems, LLC

contents

3 LETTER FROM THE PRESIDENT

5 ATLAS: THE NEW MODEL STANDARDTechnological advancements, high-profile accidents, and price fluctuations have forced companies to

reconsider how they manage pipeline assets using geometric modeling. Real-world modeling reduces

non-asset data and allows for cross-vendor management, cutting the overhead normally associated

with complex data models and easing transitions to the next generation of asset management tools.

9 GUIDE: DATA MODELS

13 ADVANCED FACILITY DATA MANAGEMENTSignificant advances in technology and data management are necessary to meet the strict regulatory

compliance challenges facing transmission pipelines in the United States. Pipeline operators have

turned to 3D modeling in order to address these challenges in a robust, sustainable, and audit-ready

manner.

18 GOVERNMENT REGULATIONS: “TVC” EXPLAINED

21 INTERVIEWEsri’s Marketing Writer Matthew McDermitt interviews Patrick Boes, a Senior GIS Analyst at Global

Information Systems, about crucial industry partnerships, data integrations, and the strides that ESRI

and Global are making towards developing a truly singular model for pipeline asset management

23 FIELD INSPECTIONS and WORKFLOWSThe successful implementation of any pipe inspection program is dependent upon the efficient

combination of various operations into a streamlined process with wide-spread user acceptance.

The use of industry standard software for all inspections has helped Energy Transfer build a process

that matches business workflows and provides a continuous feedback channel to improve overall

operations.

31 THE MARCELLUS REGIONWith roughly a billion dollars of investment by E&P companies, the Marcellus Region has emerged as

one of the most significant shale plays in the continental United States. In addition to satisfying North

America’s quest for energy independence, the investment in shale plays in and around the region have

proven crucial to an Appalachian economic revival that extends beyond the energy industry.

O I L & G A S E D I T I O N 2

R A I L

SINCE ITS FOUNDING in 2006 on the principle of customer service, Global Information Systems, LLC has grown to five offices and over 150 professional

staff members that are dedicated to focus-ing on the needs of our customers. I am very proud to say that Global Information Systems is not just a great technical services company but it is a truly great place to work. Just as we have grown in our service offer-ings and capabilities, we have continued to be joined by many of the best talents in our industry. Not only can no other techni-cal services company in our industry boast the growth that Global has experienced, I am convinced that no similar company can boast the depth of talent and true dedica-tion to customer service which comes from our staff, and it is our reason for success.

I am very proud of the fact that Global’s values of Teamwork, Passion, Trust, and Focus not only define our organization’s culture, but are exhibited by each and every member of our excellent staff. It is my hope that this publication will provide us the opportunity to showcase our fine prod-ucts and services to a larger audience and be able to expose our outstanding staff to even more great organizations.

Global’s software product offerings come from our roots in the pipeline industry and our deep understanding of data manage-ment—especially spatial data. I am often asked what it is that makes our software products different from other tools on the market. Much of what makes our products so good comes from our depth of exper-tise, but what I believe makes our tools truly different is our software philosophy. We believe in developing tools that enable real vendor independence. To that end, we build our tools such that our customers can fully utilize them independently of our services if that is their desire. We believe in bring-ing the power of data access to all users, and to do that our tools must close the loop between the office and the field. Foremost, we believe our tools should allow users to do their job more efficiently and pleasurably without the need to be data entry clerks, complex software gurus, or GIS analysts.

Global’s services focus primarily on technol-ogy services and consulting for the pipeline industry and, more recently, technology for the rail industry. Within these disciplines, we concentrate on innovative value solu-tions that utilize Geographic Information Systems, design and drafting systems, data and records management systems, and field data collection systems and services. Global’s differentiator is that we don’t just provide these services to the industry; our focus on innovation brings greater value and better solutions to our customers.

I am very excited to be able to share a few of Global’s recent innovations with you in this publication and welcome you to contact us with any questions about our services or the products that we showcase here.

Sincerely,

Fred Spickler President, Global Information Systems

O I L & G A S

SPRING 2015

FALL 2014

W E L C O M E

3 G L O B A L M A G A Z I N E

F O R M O R E I N F O R M AT I O N O N O U R P R O D U C T S

GFORMS®

GDOTCalculator

PROJECT PULSEGLOB

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At Global Information Systems, LLC, we pride ourselves on providing you with software products designed and adapted for your company’s needs. We know that no two business workflows are alike, which is why all of the products featured in this magazine are fully configurable—our industry experts will work with you to make sure that you are completely satisfied with the results.

W E L C O M E


Atlas :The New Model Standard

part of Global Information Systems’ new Atlas Platform


DATA I N T E G R I T YDATA I N T E G R I T Y

Atlas :The New M odel Standard

BETWEEN TECHNOLOGICAL ADVANCES, high-profile accidents and price f luctuations, petroleum and natural gas pipeline oper-ators work in a complex and competitive environment. Continually updating and

modifying operating practices consumes consider-able time and directly affects a company’s bottom line as regulations and requirements are ever changing. With the seemingly inevitable increase in reporting responsibilities, efficient data manage-ment is arguably more important now than it has ever been. Pipeline transmission companies need efficient data management solutions to ensure the integrity of pipeline and reporting information for regulatory entities and the public.



AT L A S ’s D E FAU LT C O N N E C T I V I T Y R U L E S

𝟙 Any polygon

that intersects

pipe segments can

be reported as an

online event with

the beginning- and

end-series informa-

tion.

𝟙 Offline poly-

gons can be shown

as the nearest start

and end locations

of the line to the

nearest pipe seg-

ment or to one

related through a

foreign key.

𝟙 For crossing

information - where

linear elements

cross a pipe - the

location of the

crossing can be

used to show an

online point with

stationing.

𝟙 For offline

point data, the

nearest perpen-

dicular location is

used for the on-

line location; the

stationing can then

be shown from the

pipe segment.

𝟙 For linear

range, the near-

est start and end

locations of the

line to the nearest

pipe segment(s) are

related through a

foreign key.

GLO B A L I N F O R M AT I O N SYSTEMS has developed a unique data platform that makes the relationships between real-world assets

and data models more intuitive, thereby allowing pipeline transmission companies to more efficiently maintain safe operations and consistent reporting. The Atlas Platform employs the concept of a spatial network to maintain relationships between elements in the model.

Text by PATRICK BOES

Each pipe segment, for instance, must connect to other pipe segments through junction features that represent facilities in the ground. Being able to have an exact depiction of pipeline infrastructure in data representations increases data quality and enables dynamic reporting capabilities, which are essential features of any data management program that is responsive to business imperatives and safety concerns.

The Atlas Platform is a geo-spatial way of tracking and maintaining pipeline assets that simplifies data maintenance, integra-tion, and reporting for gathering, trans-mission, and distribution companies. Atlas reduces the amount of non-asset data and enables cross-vendor pipeline asset

management, lowering the operational overhead normally associated with the very complex data models used by many tools available on the market today. Initially designed to use Esri’s ArcGIS tools for editing along with Esri geometric network capa-bilities, Atlas enables situational tracing and flow analysis while utilizing connec-tivity rules to maintain data quality. This allows the Atlas Platform to remain adapt-able while relying on SQL spatial types that conform to OGC standards—such as Oracle SDO_Geometry, Esri ST_Geometry, or SQL Server Geometry—to dynamically report data for 3rd party applications and data analysis.

Similar to Esri’s Utility and Pipeline Data Model (UPDM), the Atlas Platform template originates from Esri’s Gas Distribution Data Model, which was designed to ensure data quality and consistency with real-world assets. Multiple features cannot occupy the same space within the Atlas Platform and, although a specific data structure is not required, data normalization is carried out in a similar fashion. Each physical pipe-line element is stored as a feature that has both a spatial location and spatial rela-tionship to the pipe segment feature. This eliminates the need to relate several data-base objects with primary-key-to-foreign-key relationships that traditional RDBM’s



By producing an exact depiction of pipeline infrastructure through default connectivity rules like those mentioned below, Atlas intuitively reduces non-asset data, increasing data quality and enabling dynamic reporting capabilities.

employ. By storing all of a pipeline’s station and measure information in the pipe segment feature, Atlas lifts the burden of extra route data maintenance and lowers operating costs.

METHODS OF ATLAS

Pipeline operators typically group series and segments of pipe together according to a hierarchy. The hierarchy of a pipeline can vary between companies, but tradition-ally starts with the pipeline system and a line or line loop. The line loop represents a grouping of series from the source of gas to a terminal point. Atlas approaches pipeline hierarchy in the same manner. ‘Line loop’ is an object class. One of the very few data-base relationships used by Atlas connects line loop to the pipe feature class.

The Atlas Platform methodologically requires only a few core tables or features in a data store. Lines and pipes are both required to successfully maintain and report pipeline information. Pipe segments are the only feature class that house station or measure data within Atlas. The other fea-tures in the database inherit the station information from the segment or seg-ments on which they reside. For instance, a control point feature—used in APDM—can be created by querying the station values of pipe segment vertices using a database spatial method. Attributes such as line name, route id, status, x, y, and type can be included from other tables. Whenever the underlying pipe segments change in location, measure or attributes, the control point is updated. This eliminates the need to maintain a control point feature with route and station attributes.

In the event that multiple reference modes are utilized by a company, this view can be set up to report stationing on both ref-erence systems without a having to store multiple measures in pipe segment or addi-tional attributes.

Physical components of a pipeline system such as tees, taps, reducers, and valves are conventionally stored as an object or a feature. Objects reference their location through attributes; a valve, for example, is stored in a table with a route id and station value. The Atlas methodology uti-lizes a feature for each of these physical components and does not store any route or station information as attributes to the feature. Each component’s hierarchy and stationing are based on physical relation-ships to the pipe instead of standard rela-tional or linear referencing. This allows for the same traditional linear referencing information without the need to maintain attributes.

The Atlas Platform utilizes out-of-the-box Esri ArcGIS tools for data maintenance and will also integrate with the upcoming UPDM data model template. (Opposite Page: See quote from Tom Coolidge on Esri’s upcom-ing UPDM model.) Organizations that cur-rently utilize GIS software or those that might be looking to transition to new models—like Esri’s UPDM—can implement the Atlas Platform now to help them more effectively manage transmission, distribu-tion, and gathering-system assets. The con-cepts can be validated against any RDBMS supporting a SQL-, Esri-, or Oracle-compliant spatial data type. This allows operators to maintain data in one medium while display-ing and reporting it through several others.

CREATE view CONTROL_POINTAsSelectps.shape.STPointN (g_idx.n) as shape,Ps.GlobalID as STATIONSERIESEVENTID,ps.STATUS,rount(ps.shape.STPpintN(g_idx.n).M,2) as STATION,cast(round(ps.shape.STPointN(g_idx.n).STX,7) asnumeric(38,7)) as X,cast(round(ps.shape.STPointN(g_idx.n).STY,7) asnumeric(38,7)) as Y,g_idx.n as POINT_ORDER, casewhen g_idx.n = 1 then ‘BEG_CP’when g_idx.n = ps.shape.STNumPoints() then ‘END_CP’else ‘BETWEEN’end as CP_TYPEfromPIPESEGMENT_VW ps,g_idxwhereg_idx.n < = ps.shape.STNumPoints()



The illustration above shows a pipe segment

with 5 vertices and their associated measures, or

m-values. The SQL code is used to create a control_

point object from the pipe segment that reports

location, station, and route id of the vertices.

(See table to the left.) This object is automatically

updated whenever a change is made to the pipe

geometry or attributes.

A Q U I C K G U I D E TO D ATA M O D E L S - P O D S a n d A P D M

𝟙 The Pipeline Open Data Standard (PODS) is a data model designed to improve interoperability between applications and databases for

pipeline companies. Designed to handle onshore and offshore pipelines, along with gathering and distribution systems, PODS is a comprehen-

sive and robust data model. PODS supports both Oracle and SQL Server databases with its Relational Model, additionally, PODS Spatial supports

the Esri Geodatabase model for users of Esri technology. Membership with the PODS organization is required to utilize the model, while a cur-

rent membership is required to obtain the latest enhancements as they are released. As PODS association members Global is well versed in the

use of PODS along with its particular strengths for a given implementation.

𝟙 The Arc GIS Pipeline Data Model (APDM) is designed for storing information pertaining to features found in gathering and transmission

pipelines, particularly gas and liquid systems. The APDM was expressly designed for implementation as an Esri geodatabase for use with Esri’s

ArcGIS and ArcSDE® products. A geodatabase is an object-relational construct for storing and managing geographic data as features within an

industry-standard relational database management system (RDBMS). APDM differs from PODS in that it is not meant to be a comprehensive

model of all assets a pipeline may need to store, however, it does provide the ability to customize the model as required to fit particular business

requirements without falling out of compliance. For a database to be APDM compliant, only a small number of core objects and attributes are re-

quired, which provides flexibility for additional objects to inherit these properties and provide unlimited expandability. Global’s teams of experts

has been working with APDM technical and steering committees since inception and are experts in its implementation and use throughout the

industry.

MODEL FLEXIBILITY

The driving factor behind the creation of the Atlas Platform was to eliminate the barriers that keep necessary and timely information from stakeholders and a fully vested public. This necessitated a technological solution that could operate independently of cor-porate interests. Operators often find it dif-ficult to use a variety of 3rd party applications for analysis and reporting because a vendor tends to support one specific data structure over another.

Atlas accommodates all models through a series of views and stored logic that can be used to create a self-maintained APDM and/or PODS schema within the same database. This model flexibility allows Atlas to operate intuitively; no matter what model pipeline companies currently utilize, Atlas provides them access to a variety of 3rd-party appli-cations for tasks such as Class and HCA calcu-lation, alignment sheet generation, and risk calculation without the need to maintain the

data schema in which these applications typ-ically operate. For example, an operator can choose to use an alignment sheet generator that runs on PODS and a class/HCA calculator that runs on APDM without having to main-tain those specific models, and the effort it takes to maintain Atlas is much less than that of PODS or APDM independently.

In addition to lower maintenance costs, ben-efits of this approach also include a larger application pool to choose from, and Atlas eliminates need to “re-tool” when a company decides to change model structures.

Because Atlas can be registered as a series of ArcSDE feature classes and tables, it is easily integrated with Maximo SDE connectors. Using the SDE format does not restrict the ability to connect and edit data with other vendors. Any EAM software can connect through the database to the underlying tables and views, making integration with asset-management systems simple.


DATA I N T E G R I T Y


The illustration above shows a city boundary polygon intersecting with a pipe segment. Atlas utilizes the spatial relationship between the polygon and the pipe to return the begin station, end station, and route id of the city boundary without needing to store the information in an attribute. Any polygon that intersects the pipe segments can be reported as an online event.

“Availability of a practical and up-to-date data model template tailored to the unique needs of an industry is one of the keys to GIS project success at companies, whether their use of Esri software is new or long-standing. For this reason, Esri collaborates with industry and academic leaders to continually evolve a range of geodatabase data model tem-plates. The intent of Esri data model templates is to provide Esri users with a best practice, industry-specific starting point. Most users start with these data model templates, then refine and extend them to meet their specific needs and requirements. Esri data model templates “just work” with the ArcGIS platform and reflect Esri’s view of best data model practice.

“Esri’s Utility and Pipeline Data Model (UPDM) is a geodatabase data model template for opera-tors of pipe networks in the gas and hazardous liquids industries. UPDM is a moderately normal-ized data model that explicitly represents each physical compo-nent of a gas pipe network from the wellhead to the customer meter, or hazardous liquids pipe network from the wellhead to the terminal or delivery point, in a single database table object.”

~Tom Coolidge, Esri

Operators no longer need to feel trapped in the box of vendor-confining data stores and practices; with Atlas, they can have the best of all worlds. Using out-of-the-box GIS functionality and database spatial offerings allows pipeline professionals to keep prac-tices that work and revise those that don’t without data-store restrictions.

GEOMETRIC NETWORK

In order to effectively model pipeline assets based on how they exist in the real world, Atlas employs a geometric network. The network allows situational tracing and flow analysis, and it utilizes connectivity rules to maintain data quality.

Atlas’s connectivity rules allow the system to be traced based on operational and regula-tory requirements. By integrating this prac-tice with EAM systems, operators can easily identify where any given piece of hardware has been placed. It becomes easy to visu-alize and symbolize live-flow SCADA infor-mation across the system by tying it to the network. And, through the use of flow analy-sis, operators can create schematic layouts of gas control systems without having to main-tain multiple data stores for different working entities.

Network connectivity also keeps pipeline components in spatial unison with the routes. When editors need to adjust the route geom-etry, they can simply move the line; the geom-etry of spatially related route features will be updated without any of the extra work tradi-tionally associated with the editing process.

With a geometric network, operators can trace a set of pipes for the purpose of pipe-line analysis. These traces depict real-world scenarios. Operators can “turn-off” a valve at one location and “turn-on” another in order to see how flow is affected within the line. With the assistance of trace weights—factors such as cathodic protection resistance values and pipe operating pressure—users can perform advanced situational traces that depict accu-mulations along the pipe. Weights are also

used to isolate upstream and downstream situations.

Tracing is another useful reporting tool. Users can trace gas source to terminus and return a report of from and to routes for use in class and HCA studies. Therefore, from and to route attributes do not require maintenance.

A network also offers connectivity rules that force a model to conform to the way pipe-lines are constructed. For example, a 6-inch diameter pipe segment is unable to connect to a 4-inch diameter pipe segment unless a reducer is present between them. Business rules for MAOP—based on date of construc-tion, material, or other criteria—are easily val-idated and enforced using the data manage-ment practices implicit in Atlas’s architecture.

SIMPLIFIED DATA COLLECTION

The Atlas Platform is capable of working alongside existing workflows, allowing data to be collected without interruptions to standing business models. Survey data is easily migrated into Atlas allowing ease of integration with construction and engineer-ing information. Operators who are inter-ested in implementing the Atlas Platform are not required to have solution-specific hardware, giving them the freedom to utilize GPS devices, tablets, or even location-aware mobile phones.

SUMMARY

Advances in GIS and database technology have created the opportunity to view pipe-line data management in a whole new light. Operators no longer need to feel trapped in the box of vendor-confining data stores and practices; they now have the freedom to experience the best of all worlds by imple-menting an adaptable solution like Atlas.

Atlas is not a commercial product. The prac-tices carried out with Atlas require no custom software. These ideas are intended to open communication for simplified data manage-ment within the pipeline industry. 𝟙

O I L & G A S E D I T I O N 1 0


GFORMS®GForms® streamlines complex work activities, transforming work processes and their documentation requirements into simple, guided user tasks. Eliminate the hassle of redundant paperwork, filing, storage, and maintenance. Start collecting your pipeline and facility data consistently today. Search, analyze, and report out your information in real time with this comprehensive platform that makes complete and accurate data collection a reality.

GForms® is designed to operate seamlessly in both connected and disconnected modes. Every day thousands of users gather pipeline data from virtually anywhere and flawlessly synchronize their reports and inspections with the GForms® master application whenever they have connec-tivity. As a field technician, getting your next as-signment is as easy as opening your inbox where forms are already prepped and await your com-pletion.

Whether in the office or in the field, GForms® em-powers your team with the convenience to use the platform or mobile device that is right for them; the ease of answering only questions that are relevant; mapping and location data when-ever they need it; the ability to take photos and turn them into sketches; and the confidence that absolutely everything they collect will securely and automatically be delivered to its destination.

With the GForms® Form Designer you can pro-fessionally develop your own, unique and data-aware templates from scratch or simply modify a copied template from the vast GForms® Pipeline Template Library. Once you have your template ready and linked to your corporate data, you can

launch your custom data collection workflow to a chosen set of users and require their reports and inspections to go through an automated approv-al process.

GForms® contains built in integration points for third-party software and database management systems that allow you to instantly create a live connection or import information into GForms® from a variety of sources for use in field valida-tions, filtered drop-downs, or even lookup table calculations. Export the data you collect or con-nect live to third-party EAM systems and GIS models such as APDM, PODS, the new Atlas Plat-form™, or Esri’s UPDM.

Use the GForms® Web Portal to monitor work processes in real time, intuitively query for data individually or across your whole system, in-vestigate trends, generate statistics, and build and export reports all within in the attractive GForms®standard dashboard.

GForms® closes the loop between the office and the field, making every work task a guided pro-cess and every activity instantly traceable, auto-matically verifiable, and always complete.

1 1 G L O B A L M A G A Z I N E




Model Compliance

R E G U L ATO RY C O M P L I A N C E


Model Compliance

IN AN EFFORT to manage complex regulatory compliance data, pipe-line operators are reconfiguring how they store, visualize, analyze, and sustain asset data related to

their above-ground facilities. Driven by an increasingly stringent regulatory environment and rapidly growing data complexity, operators see the need to adopt a more sophisticated approach.

To meet these challenges, operators are developing a core data store of intelligent 3D models built in AutoCAD Plant 3D. Each model represents the mechanical assets within a facility and can store characteristic information—from the Specified Minimum Yield Strength of a pipe (SMYS) to its instal-lation date—down to the component level. Regulatory compliance informa-tion, including Maximum Operating Pressure (MOP), is also calculated and stored at the component level. These intelligent models are then published to users as interactive 3D models on the web, desktop, or mobile devices.

Text by ERIC KLEIN

While the individual 3D models are pow-erful tools, operators are increasingly storing the data behind each model in an enterprise database, which dras-tically increases the value of the data by enabling greater analytical and data management capabilities. Users can now query across all facilities for com-ponents that meet specific physical or regulatory criteria and locate them in the appropriate facility. Additionally, as regulatory requirements and manage-ment practices evolve, the data behind the models can be updated without editing each model individually.

The value of using these technologies can be further extended by storing and maintaining the full complement of as-built facility drawings in the same



L

models, reducing the need to manage multiple drawings and/or data sets.

A GIS SOLUTION

Both operators and service providers alike have developed pro-cesses and solutions to house, track, and manage the massive amounts of data generated in these efforts to further support the Traceable, Verifiable, and Complete doctrine established by PHMSA in 2012. (See page 18 for additional information on the TVC doc-trine). Some of these systems are proprietary and are being mar-keted to the industry; others are homegrown by the operator and are not publicly available, and still others are simply combina-tions of off-the-shelf applications and data management tools. One commonality among these systems is the use of Geographic Information Systems (GIS) as a core technology, which is a natural fit for the need.

Several traits of GIS make it well suited for this purpose:

1) GIS implementations tend to have a robust database system at the core of the implementation.

2) Pipeline GIS is fairly mature with several industry standard data models available to leverage and upon which to build.

3) The ability to manage and visualize linear assets is a core GIS capability that has been utilized and enhanced by the pipeline industry for decades.

4) GIS is used in some capacity by almost all pipeline operators, some of whom use GIS as a mission-critical operational system.

5) GIS provides out-of-the-box or easily built interfaces that allow users (and auditors) to quickly report on or interrogate individual components thereby verifying that the characteristics are accurate and supported by TVC documentation.

FROM LINE PIPE TO FACILITY MAINTENANCE

Now that the industry has started to get a handle on line pipe—from PHMSA’s perspective—attention is shifting to the opera-tors’ facilities beyond gathering and transmission. It can only be assumed that the lessons learned on line pipe and the regulatory scrutiny applied to it are equally valid for facilities.

These tools and lessons are invaluable, but facilities tend to be vastly different. Global Information Systems evaluated several tech-nologies in an effort to determine the most suitable approach to calculating, managing, reporting, and maintaining operating pres-sure-related data. Specifically, we evaluated GIS, 2-Dimensional CAD, and 3-Dimensional CAD. In the end, we determined that 3D CAD and, more specifically, AutoCAD Plant 3D, was the most appro-priate technology to manage this data for the following reasons:

1) GIS, while proven to be an excellent solution for line pipe, strug-gles to adequately manage or visualize true 3D data. Any case where two assets share an X,Y coordinate presents a challenge for GIS to represent and visualize this information and, consequently, it becomes difficult for users to manage and query this information. Stacked or vertically oriented assets that share X,Y coordinates are abundant in pipeline facilities.

Excerpt from a 3D CAD Bill of Materials



3D CAD solutions allow for the development of hierarchical MAOP/MOP data models so that values can be calculated at multiple levels—from individual components to pressure zones and even entire facilities. With this capacity, operators can optimize operating pressures with high levels of confidence.

LEFT: Hierarchy Model

2) 2-Dimensional CAD is better able to manage and present ver-tically stacked assets, but doing so requires multiple drawings and the user must have experience to properly read and interpret them. Additionally, the management and updating of the exten-sive number of drawings required to present the necessary detail and perspective is significant.

3D CAD provides a unique combination of incredibly powerful visualization capabilities and robust database-driven data man-agement tools that cannot be found in any other environment. Additionally, the vast majority of as-built information readily avail-able on non-line pipe facilities already exists in a CAD format; this includes as-built mechanical drawings, bill of materials, isometric drawings, and elevation profiles among others. In most cases, the workflow to integrate these existing drawings into a master 3D model of the facility is almost seamless.

The 3D model of a facility can be used to present complex facility layout information in a detailed, yet intuitive and understandable way. The figure on the opposite page is an excerpt from a 3D CAD Bill of Materials that clearly identifies each component, the config-uration of each component, and its relationship to adjacent com-ponents. A 3D CAD solution allows for the development of a hier-archical MAOP/MOP data model and by doing so, the MAOP/MOP can be calculated at the component level, the pressure zone level, and the overall facility level. This capacity allows the operator to optimize operating pressure within the facility with a high level of granularity and confidence. An example implementation of this model can been seen below.

FOR THE ENTIRE ENTERPRISE

In most organizations, CAD is not an enterprise solution, meaning that data created in CAD is not centrally managed nor is it avail-able to multiple users and/or systems on demand. If implemented properly, a 3D CAD solution using AutoCAD Plant 3D can be such an enterprise system. By using Microsoft SQL Server as the underlying database technology for the 3D models, all data being housed and managed in the 3D facility models can be available to query, report on, update, and analyze in real time without needing the compli-cated or expensive native client application. By storing the docu-ment properties of the supporting documentation of each compo-nent in the database, links can be created between the 3D model and the documents stored in a document management system.

One critical measure of success in an enterprise data management solution is how accessible the data is to business users and decision makers. A properly architected 3D data management solution can provide access to data housed in complex systems through simple and intuitive user interfaces. Web-based document management systems and web-based 3D model viewing applications provide access to the data housed and managed in 3D models and associ-ated document management systems via intuitive web interfaces that eliminate the need for complicated and expensive 3D mod-eling applications. This data access approach puts the data in the hands of the business users and decision makers while enabling rapid and confident audit support.

The application of 3 Dimensional CAD can provide a responsible and sustainable solution to meet the current and expected MAOP/MOP regulatory compliance requirements of pipeline operators in non-line pipe facilities. Furthermore, if the solution is designed and implemented as an enterprise solution, the data and tools devel-oped for the compliance effort can be managed across the busi-ness to inform operational planning and decision making.

OPERATIONAL BENEFITS

Beyond and in addition to the regulatory compliance value of this technology are operational benefits that include improved CAD data management and enhanced asset data management. Specifically, the development of 3D CAD models to house and maintain mechanical asset data can provide a highly efficient, sus-tainable drawing management solution. Rather than maintaining tens, hundreds, or even thousands of mechanical as-built drawings depicting all views and elevation profiles within a particular facility, a single 3D model of that facility can be used to develop 2D draw-ings for maintenance, project scoping, and construction support on an as-needed basis thus eliminating the need to continuously update multiple dependent, redundant drawings. If modifications



TVC

Eric Klein is the Director of Atlanta Operations for Global Information Systems. Eric oversees Global’s CAD Division, developing innovative applications to improve organizational processes across a pipeline’s operations. Eric has a proven history of transforming GIS departments into streamlined operations that are capable of delivering solid investment returns.

are made to a facility, the 3D model is updated accordingly and the as-built conditions are captured.

In a recent case, more than 1500 as-built 2D CAD drawings were updated to as-built conditions based on new information provided by the contract-engineering firm. As a pilot project, one facility was redrawn in 3D and 2D plans and profiles were cut from the 3D model. The initial effort was approximately 20% more expen-sive than simply redrawing the set in 2D. Savings on subsequent updates, however, are expected to exceed 50% representing a sig-nificant and fast return on investment.

Database reporting capability can be leveraged for high-value asset management purposes; the database behind the models can be queried to locate all like components by facility and precise loca-tion within the facility because the make and specifications of all components have been captured and validated in the models. This information can be used, for example, to locate all valves from a particular maker purchased/installed in a specific date range for service or replacement.

This component-based data structure—including the 3D asset location—can be tied to other asset management and work man-agement systems, including Maximo and SAP. Integration can occur at many levels, but having common specifications and a com-ponent-definition hierarchy is a solid foundation approach to inte-grating these systems at appropriate levels and using each system to its best advantage. Integration with a procurement system has been an effective means to provide a sustainable documentation reference for both historical and current work. This approach has allowed engineering and regulatory compliance teams to access Purchase Orders, Material Test Reports and like documentation without developing a second, redundant document store.

SUMMARY

By leveraging the value of storing attribute data inside of a system that can be accessed by many users in an organization, opera-tors are realizing benefits of 3D modeling in ways they never have before. 𝟙

GDOTcalculator

GDOT Calculator is a full-service tool designed to simplify and expedite DOT Class and HCA iden-tification and change detection. With broad da-tabase compatibility, user-specified tracking, analysis tools, and configurable parameters for standard calculations, GDOT Calculator is your answer to Class and HCA requirements.

Our robust suite of analysis tools and reporting functions allow users to review, analyze, accept, and integrate Class changes. Track and analyze a user-specified set of lines or line types, calcula-tion parameters, and base or comparison proj-ects. Automatically compare calculations to base project areas of change which can then be ana-lyzed to determine the cause in graphic or tabu-lar reports.

Simplify Your Workflow. With GDOT Calculator software, Sliding Mile and Clustered Class calcu-lations are consistent with 49 CFR 192.5, and HCA calculations are consistent with 49 CFR 192.905. Calculations can be performed interactively with a graphical user interface or in a batch mode for hands-off processing.

Easy Tracking and Review. Configure parameters for standard calculations or what-if scenarios, in-cluding: zone length and width; Class and HCA density thresholds; gas factor; and controlling structure methods, like perpendicular offset or arc intersection. Quickly review user-specified parameters, areas of change, change factors, and results in the database and track all calculations, changes, Potential Impact Radius (PIRs), and structure listings.

Fully Integrated. No need to change your data-base model. Our software operates directly in APDM, PODS, ISAT, and custom database models.



TRACEABLE, VERIFIABLE, AND COMPLETEFEDERAL STANDARDS

Text by ERIC KLEIN

Significant advances have been made in terms of both technology and the data management process in order to meet the strict regu-latory compliance challenges faced by transmission pipelines in the United States. The technologies and data management approaches currently employed are not, however, optimized or even adequate to handle the infrastructure complexity of non-line pipe facilities such as compressor stations and storage facilities. New approaches and technologies are necessary to address these issues in a robust, sustainable, and audit-ready manner.

Using new technologies in new ways has inevitable challenges and this effort is no exception, which is why any discussion of techno-logical advances should carefully consider and faithfully outline the lessons learned and best practices.

In the wake of several high-profile pipeline accidents in recent years, regulators are under pressure from legislators to demon-strate a greatly improved assessment of operational pipeline assets and, consequently, are applying that pressure to operators. In response to ever-increasing regulatory scrutiny from PHMSA and other federal regulatory bodies, pipeline operators are extending their ability to calculate, manage, and substantiate the Maximum Allowable Operating Pressure (MAOP) of their systems in the case of natural gas pipeline and Maximum Operating Pressure (MOP) in the case of hazardous liquids pipelines.

The discovery, validation, calculation, and management of MAOP and MOP-related data on line pipe—i.e., transmission pipeline segments—is generally well understood; numerous systems and approaches have been successfully implemented to meet the increasing regulatory demands from federal and state agencies. Line pipe MAOP calculation is particularly well established and the methods have matured largely because this was the first area of focus for regulatory agencies. During the implementation and enforcement of new regulatory compliance standards in MAOP calculation and documentation, PHMSA refined and clarified the interpretation of several key regulatory rules through the issuance of Advisory Bulletins. Advisory Bulletin ADB-2012-06 defines a par-ticularly murky set of standards that operators were to be held accountable for with respect to historical documentation require-ments for MAOP-related asset characteristics. All documentation is to be Traceable, Verifiable, and Complete (TVC):

“Traceable records are those which can be clearly linked to orig-inal information about a pipeline segment or facility. Traceable records might include pipe mill records, purchase requisition, or as-built documentation indicating minimum pipe yield strength, seam type, wall thickness and diameter. Careful attention should be given to records transcribed from original documents as they may contain errors. Information from a transcribed document, in many cases, should be verified with complementary or support-ing documents.

“Verifiable records are those in which information is confirmed by other complementary, but separate, documentation. Verifiable records might include contract specifications for a pressure test of a line segment complemented by pressure charts or field logs. Another example might include a purchase order to a pipe mill with pipe specifications verified by a metallurgical test of a coupon pulled from the same pipe segment. In general, the only accept-able use of an affidavit would be as a complementary document, prepared and signed at the time of the test or inspection by an individual who would have reason to be familiar with the test or inspection.

“Complete records are those in which the record is finalized as evidenced by a signature, date or other appropriate marking. For example, a complete pressure testing record should identify a specific segment of pipe, who conducted the test, the dura-tion of the test, the test medium, temperatures, accurate pres-sure readings, and elevation information as applicable. An incom-plete record might reflect that the pressure test was initiated, failed and restarted without conclusive indication of a successful test. A record that cannot be specifically linked to an individual pipe segment is not a complete record for that segment. Incomplete or partial records are not an adequate basis for establishing MAOP or MOP. If records are unknown or unknowable, a more conservative approach is indicated.” [PHMSA ADB-2012-06 (2012)]

The result of these definitions has been a substantial undertaking on the part of regulated pipeline operators to mine their histori-cal as-built and purchasing records to determine asset properties. Additional work is necessary for them to adequately support their findings with documentation that meets the TVC standard prior to calculating MAOP or MOP. 𝟙

TVCR E G U L ATO RY C O M P L I A N C E




...because we’re better than that.

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Global ReporterAs today’s Oil & Gas Operators continue to grow through both expansion and acquisition, the need for system integrity and compliance reporting across these systems becomes increas-ingly complex. Meanwhile, the regulatory demand for information is becoming progres-sively more onerous. Attempting to group together all the information needed for report-ing from disconnected systems is a daunting and time-consuming task. The results of these endeavors are often confusing, not easily traceable, and arrive too late for adequate scrutiny.

Originally designed to afford operators the inde-pendence to build and publish their own reports, Global Reporter™ has evolved into an exception-ally flexible tool for effective and traceable cross-platform reporting in real time. Global Reporter™ can simultaneously query across multiple Oracle and MS SQL Server instances without ever jeop-ardizing data integrity to deliver complex reports from live data at the press of a button.

Global Reporter™ encourages more interactive data analysis by overcoming the standard inflexi-bilities of traditional reports. Your data is automat-ically and safely captured from static formats and translated into dynamic reports that you config-ure and control.

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reports on demand.

Experience data review like never before with a user-driven system that facilitates safe access across organizational data sets and leverages intu-itive charts that effectively translate raw data into usable information on demand.



&Global Esri

01 Global Information Systems has been partners with Esri since 2007, but for those who don’t know your company, tell us a little more about you. We are a full-service application devel-opment and GIS products and services company focused on the Energy Industry. We provide complete service solutions and customer-configurable software products for our clients. We specialize in software development, database implementation, GIS, CAD-to-GIS integration, and consult-ing. Our GIS team prides itself on being the best in the industry, and part of our compet-itive edge is the way that we utilize cutting edge Esri technology to offer the best solu-tions to our clients.

Esri’s Marketing Writer Matthew DeMeritt

interviews Patrick Boes, the GIS Manager for Global

Information Systems, about the precursor to Global’s

new Atlas Platform, GNET.


I N T E R V I E W

Our work is centered on making data accessible, usable, and interactive—that is, and always will be, our mission.

~ Patrick Boes, GISP

03 Can you speak to one of those implementations?We had a pipeline company located in the Northeastern part of the Unites States approach us with the need to migrate their data into a data model that could be edited simply inside the ArcMAP workspace with out-of-the-box editing tools and the ability to run DOT class studies and report on HCA’s—or, High Consequence Areas. Utilizing GNET, we gave this operator the ability to calculate online and offline locations for lines and points on the fly without the need to perform any post-processing calculations. The linear referencing system is self-maintained, which lifts the requirement to populate extra attributes. In this scenario, we also set up a geometric network in the data model that allowed the client to trace a pipeline in its entirety and report out the results for DOT class analysis. The geometric network also assisted this operator in improv-ing data quality by utilizing the network connectivity rules. We found this to be much quicker and easier to maintain than other models used in the past.

Patrick Boes, GISP, has over 12 years of GIS experience. He is responsible for managing projects that range from custom software development to PHMSA special permit data exploration. His work specifically focuses on GIS data organization and implementation. In his career as a senior GIS consultant, Patrick has contributed to the design of commercial, off-the-shelf products for the natural gas transmission industry that are widely used by companies needing to manage extensive pipeline networks.

04 What specifically makes GNET different from other data models?GNET was designed to be maintained with out-of-the-box Esri technol-ogy without the need for any extra, third-party software or plug-ins. The designers of this model at Global had one clear goal in mind when developing GNET, which was to keep it simple and to base the model on technologies that our client’s already own. GNET’s strategy also relies on SQL spatial types—like Oracle Spatial, Esri ST_Geometry, and SQL Server Geometry—to dynamically report data for 3rd-party application and data analysis. This means that operators have the choice to use a variety of software vendors to manage DOT compliance without the need to pigeon hole their data into a specific structure for maintenance.

02 What are some of the new ways that you have utilized Esri technology?Most recently, we have been working on a new data model for the transmission pipeline industry. We call it GNET, and it is quite a bit different from other indus-try standard models utilized by operators today. It has been adopted by several North American natural gas organizations and has really helped simplify the way their data is managed.

05 So, what’s in your future? We’re looking to expand our partnership with Esri, embedding Esri functionality for one of our most utilized software prod-ucts, GForms®. We’re also building a pipe-line public safety website that will allow emergency departments to log on to the site to view all shared information for haz-ardous materials. And, we’re developing a Right of Way management system to allow for a more interactive user experience. All of our current work and our future projects center on making data accessible, usable, and interactive in a way that addresses our clients’ top concerns. That is and always will be our mission.


I N T E R V I E W

The PIPELINE INSPECTIONLIFECYCLEEnergy Transfer owns and operates approximately 43,000 miles of gas and liquid pipelines. For large and diversified holders of energy assets, like Energy Transfer, efficient business workflows are critical to everyday operations. Widespread user acceptance and continuous feedback are necessary to ensure the success and adaptability of asset integrity solutions and improved system functionality.

Troy Walda is the Chief Technology Officer for Global Information Systems. Troy oversees software development teams, products, and IT systems. Troy has over 15 years experience in technical develop-ment and business system integration. His career has focused on solving complex business problems through the use of technology while understanding and emphasizing usability by end users. Having a network of over 5000 users running Global’s software in the pipeline industry, Troy is currently focused on improving construction project management through custom software development and integrations that simplify work in the field and office.

A S S E T I N T E G R I T Y M A N A G E M E N T


ENERGY TRANSFER RECENTLY replaced their field-inspec-tion program with a comprehensive solution that inte-grates the entire pipe inspection lifecycle. Designed by Global Information Systems, the system encompasses aerial observations, pipe exposures, foreign line cross-

ings, in-line inspections, anomaly remediation, pipe inspection, and integrity sheet generation. In order to ensure the integrity of the pipe inspection program, the field inspection solution was designed with full audit-trail capabilities, front-side data validation, and full integration with the corporate-wide GIS and Engineering Data Management System (EDMS). In addition to ensuring the con-tinued integrity of ETE’s inspection program, Global incorporated a highly intuitive and user-friendly interface to encourage user acceptance and frequent use of the new technology which also featured interactive mapping functionality, very high reliability, a process-driven architecture, and the ability to work equally well in both connected and disconnected environments.

Text by TROY WALDA

For companies similar in size and with diverse assets like Energy Transfer, distributing corporate GIS systems across independent instances with server pools and large-scale relational database management systems (RDBMS) ensures the establishment of con-sistent and reliable feedback loops. This enables real-time report-ing and effective monitoring of the overall inspection process from both the field and office. In order to effectively report on all pipe inspection activities across the enterprise, the field inspection

system and the inspection process must be capable of interacting with each server and RDBMS instance, even though the inspection system and process remain functionally independent.

The inspection system that is currently in use at Energy Transfer hosts over 1,200 employees and contractors and handles approx-imately 15,000 inspections annually. It supports a variety of devices—such as laptops, tablet computers, and iOS devices (i.e., iPads, iPhones)—to accommodate all types of users. Whether on foot, in vehicles or aircraft, users can enter information from the platform that best meets the needs of their individual environment. Information collected on any device is available for continuance of the pipe inspection lifecycle on any other device and is available in real time at the corporate offices via a Web portal. While inter-changeability encourages quick adoption of the technological solu-tion, the Web portal connects users virtually by providing visual-ization tools for both business and engineering analysis such as progress tracking and remediation planning. These functions are supported through the portal’s integrated mapping, dash board-ing, and a reporting functionality that includes advanced search capabilities for both comparative and predictive analysis.

In addition to utilization for the pipe inspection lifecycle, the inspec-tion system is being used for a variety of other inspection and reg-ulatory compliance-related activities, including: cathodic protec-tion, incident reporting, corrosion assessment, DOT structure loca-tion, MAOP-MOP establishment, shallow cover, unmetered gas loss, and many more right-of-way related activities.



ETE: CASE STUDY AND IMPLEMENTATION

ETE owns and operates one of the largest and most diversified portfolios of energy assets in the United States. The ETE family of companies owns more than 56,000 miles of natural gas, natural gas liquids, refined products, and crude oil pipelines. The immense size of ETE’s operations requires distributed IT and GIS systems consisting of seven independent, large-scale relational database management systems. The distributed nature of the work across the U.S. requires well-maintained and documented processes that are able to support thou-sands of staff in the field while maintaining simplicity, consistency, and integrity.

In 2012, ETE made a series of strategic purchases result-ing in a significant expansion of operations. As a result, a number of processes had to be reviewed and updated to handle the operational and personnel expansions.

The large number of pipeline miles across ETE’s opera-tions meant that a significant number of Pipe Inspections & Evaluations (PIE) were, and continue to be, conducted on a yearly basis. After ETE’s strategic expansion project was completed in 2012, they reviewed the pipe inspec-tion process and started working to replace their PIE application with a new application featuring improved interfaces and streamline workflows.

The updated version allows pipe inspection informa-tion to be gathered on Windows or iOS devices in a dis-connected state, enabling ETE’s large pool of inspectors to gather information on remote assets in a way that is consistent with the demand for high-quality data. When user connectivity is restored, the digitally gath-ered data can uploaded to and synchronized with a central repository where it is analyzed and ultimately returned to users in a variety of configurable and more consumable formats.

Digitally collecting data in the field ensures data integ-rity by enhancing accuracy and creating audit trails. By utilizing an out-of-the-box software solution, users can collaborate across separate teams on the same inspec-tion documentation. A dynamic workflow ensures that tasks are completed as they are organized in addition to allowing for supervisory control of critical milestones within the scope of the project. As team members com-plete inspection and evaluation information, all critical elements are compiled and available online.

PIPE INSPECTION WORKFLOW

Pipeline inspections are required any time a pipeline is exposed. Pipe exposures can be caused by a variety of planned work activities and accidental exposures. As a result, pipe inspection information must have the ability to be gathered through a variety of workflows and on a variety of devices to cover each scenario.

With Global Information Systems pipe inspection reporting software, users have the ability to generate an electronic pipe inspection as an ad hoc report at any time. (The only restriction placed on a user’s ability to generate reports is set with role-based permissions.)

A pipe inspection may also have to be completed as the result of a sequence of answers to questions from other reports. Typical sequences might involve pipe inspections as the result of foreign-line crossings. The sequence of questions on reports—like foreign-line crossings—can force the auto creation of a pipe inspec-tion report, eventually sending that report to the pipe specialist for the specified area identified through GPS coordinates or location information gathered during the reporting process.

Pipeline specialists begin the pipe inspection process by entering general inspection information. The general inspection section prompts users to record information regarding the location of the pipe inspection, includ-ing: internal inspection, coating, and soil information. Depending on the reason for the inspection, wheel count can be used from an in-line inspection in place of station numbers to describe locations.

Near the end of the general inspection section, the pipeline specialist is asked if any indicators were iden-tified. If indicators were identified, the pipeline spe-cialist may fill out the evaluation section of the form or upload the partially completed inspection form to an area corrosion technician. If no indicators were iden-tified, the pipe inspection form can be finalized and uploaded to an approver.

In the event that indicators were found, the appro-priate user will be prompted to fill out an additional section of the pipeline inspection report: the evaluation form. Following a similar flow as the indicator section of general inspection form, the inspector will be asked if any repairs are required. If repairs are required, the



user can continue filling out the report or—lacking the required permission—the user may upload the report to the division construction manager. If no repairs are required, the user can save and finalize the report and upload it to be approved by a supervisor.

The final phase of the workflow within a pipe inspection repair form gives users the ability to identify anomaly remediation. If anomalies were remediated during the inspection process, the user can save and upload the report, which is then sent to an area corrosion tech-nician. If anomalies were not remediated, reports are saved and uploaded to be reviewed by an approver. The area corrosion technician can complete a review on the same inspection form and, once completed, save and finalize it as a single report.

Once a report has hit the finalization stage, the infor-mation in the form is permanently available for review via a centralized portal query screen. The information within each electronic form is also sent to a GIS team for review and can be automatically loaded to a geo-graphic information system or manually reviewed and as-built—depending on complexity of the information. The information can then be traced back to the original

event or person that triggered the inspection thereby establishing an audit trail that encompasses the entire pipeline inspection.

PIPE INSPECTION PROCESS

The pipe inspection process can be initiated in four typical ways:

1. A pipe inspection form is automatically created as part of a foreign-line crossing report if the pipeline was exposed. In the event that the pipeline was exposed as part of a foreign-line crossing, an email will be sent immediately to the inspector who submitted the initial form with a link to the additional pipe inspection form.

All forms are available and accessible online; addition-ally, forms can be downloaded to the client application prior to inspectors entering the field so that they can access them remotely.

2. The desktop or iOS application can be used to initi-ate a new pipe inspection report in an ad hoc manner.

3. The web portal can be used to initiate a new pipe



The inspection system is being used

in a variety of other compliance-related activities, including:

Cathodic Protection, incident reporting,

corrosion assessments, DOT structure

location, MAOP-MOP establishment, shallow

cover, unmetered gas loss, and many more right-of-way related

activities.

inspection report while in a connected mode.

4. The map portal can be used to select a location generate a report with an auto-generated location hierarchy. Users maintain the ability to edit auto-generated location data for improved accuracy.

The objective of the improved pipe inspection process is to make it as easy as possible to initiate the pipe inspection; it also ensures that proper users with the proper qualifications complete each section of the report. Currently the pipe inspection process is supported on any up-to-date web browser, windows application, and iOS device with plans to accommodate android devices in the future. All supported hardware accommodates a variety of GPS devices including onboard GPS, sub-3-meter blue tooth devices, and sub-meter GPS devices such as Trimble GeoXT. Based on GPS coordinates, engineering stationing can be calculated and popu-lated on the pipe inspection report.

In addition to manually entering information, any number of files can be attached to each report—such as pictures, spreadsheets, or PDF’s—to improve the data quality and to help visualize inspec-tions as if from the field.

EVALUATION PROCESS

The evaluation section of the pipe inspection form is designed for Area Corrosion Technicians to document indications of leaks, cor-rosion, mechanical damage, or linear indicators. The evaluation section also allows technicians to evaluate if a repair is required for any one of the indicators.

If leaks are observed, the user is prompted to enter basic infor-mation about the leak—such as type of leak, valve section and station—and has the ability to add comments and attachments to capture and visualize the situation. Users can enter multiple leak forms if required.

The corrosion form section can be activated if corrosion is observed on the pipe segment. The same location information as the leak is required; in addition, the corrosion inspection form requires users to input distances from the upstream and downstream girth welds as well as the wheel count from in-line inspection data if available. The type, length, width, depth, and orientation of the corrosion is documented along with the safe pressure, method, and wall thick-ness of the pipe. Users have the ability to attach multiple corrosion forms to each section in addition to pictures, which are invaluable documents for the evaluation of corrosion.

Mechanical damage can be entered on the damage form for each instance of damage observed. Damage to the pipe is documented

in similar fashion as on the corrosion form, delineated as damage versus corrosion when loaded to the database.

Linear Indications can also be captured in the pipe inspection report. As with the damage and corrosion forms, specific infor-mation is entered as it relates to the location and size of the linear indicator. Users may also identify if the indicator is part of a colony, which can help to identify if further investigation is required.

In addition to the indicators, if a non-destructive evaluation was performed, this information can be captured as part of the pipe inspection form. The evaluation date and the name of the person performing the evaluation can be captured along with general comments and associated pictures and documentation.

The final section of the evaluation form allows a user to continue by adding a repair section to any of the evaluations that require repairs; the user can subsequently pass the form to the division construction manager or area corrosion technician. If the evalua-tions do not necessitate repairs, the pipe inspection form can be finalized and uploaded to an approver for completion.

REPAIR PROCESS

If repairs are required as a result of the evaluation process, the pipe inspection report will continue to add form sections to allow for the documentation of all repairs. Repairs to the pipe may include the installation of new pipe, sleeves or damage prevention items, along with grinding and recoating. These activities are captured currently in the electronic form, while the pipe inspection appli-cation is being expanded to handle more comprehensive repairs that have traditionally been as-built.

The repair form collects general data regarding the information provider and repair date along with any damage or work order numbers that should be associated with the repair. As with all pipe inspection form sections, documents and pictures can be cap-tured and associated to the repair form for additional documen-tation support.

The installation of sleeves and new pipe segments are the two primary types of repairs that are documented in the current pipe inspection process that relate to new installations. Each sleeve installed for a repair requires its own form within the pipe inspec-tion report. Information about the sleeve is gathered including location information, type, wall thickness, and grade. Information regarding the purchase order number and mill information—such as heat number—can be included in the form to ensure that records are complete. A new pipe segment requires the same information; in addition, the user is prompted to enter information regarding the



plant, long and girth welds, and whether or not the pipe is inter-nally coated. If new pipe is installed, the user is prompted to enter additional information—such as the coating and hydro test infor-mation—to demonstrate that the pipe was properly installed and meets design requirements. Both form sections allow for the addi-tion of comments, documents, and pictures.

Grinding and pipe recoats are the two primary types of repairs that do not involve pipe replacement or sleeves installation. The grind-ing form section allows the user to enter pertinent location infor-mation, along with the initial wall thickness, ending wall thickness, and length of the grinding. Recoats are similar but also require addi-tional information to document the type of coating and material, ensuring proper documentation.

In terms of preventative repair measures, users have the ability to document efforts taken to mitigate the potential for damage on prevention forms. Location information is captured on this form, along with the type, material, and date completed for the damage prevention measures.

The final question on the repair form prompts users to identify any anomalies that need to be remediated as a result of the repair. If anomalies are present, the user can save the report and forward it to the area corrosion technician. If no anomalies need remedia-tion, the pipe inspection report is saved, finalized, and uploaded to an approver for review.

REMEDIATION PROCESS

The current anomaly remediation process must be completed when a user is connected to the pipe inspection portal. Anomaly remediations can only be performed by area corrosion technicians based on the repairs completed while the pipe was exposed. The pipe inspection software controls access and permissions so that only qualified personnel can complete work and sign off on reports.

The corrosion technician for the area is notified immediately when anomalies require remediation upon upload of the pipe inspec-tion report from the field. Anomalies in the remediation portal can be reviewed for the pipe inspection segment, including one-hundred feet upstream and downstream to account for variations in odometer readings. As part of the remediation, the corrosion technician can apply field collected actuals to in-line inspection data to refine the location of anomalies as recorded in the GIS. The report can be saved once the corrosion technician has selected all the anomalies that have been remediated. The associated anoma-lies are then added to the bottom of the remediation report which can be downloaded and worked on in a disconnected state, saved and loaded to GIS.

Documents are loaded nightly to GIS; all information is loaded into a version and reviewed before being accepted as production GIS data. This process is currently being updated so that pipeline specialists in the field will have a list of all relevant anomalies for the location of the pipe inspection along with the ability to select which anomalies are remediated as part of each repair.

BACTERIA TEST PROCESS

The bacteria test form can also be triggered by selecting certain options in the general inspection section of the pipe inspection report. If a user has indicated that a bacteria test was performed upon uploading the pipe inspection report, a bacteria test form will automatically generate on the server with pertinent location information for the area corrosion technician to complete. When results of the soil bacteria test are returned from the lab, the area corrosion technician is required to open the relevant pipe inspec-tion report and document the results of the soil tests to complete the entire pipe inspection process.

ADMINISTRATION

Administration of the pipe inspection application is handled through the central portal which can be tied to a windows-active directory for centralized administration or work independently of other IT systems. Setup and configuration is straight forward—requiring basic username, email, and operating area information. Users can also be associated to specific roles such as division con-struction manager or area corrosion technician.

The pipe inspection application routes reports to appropriate users based on the identification of user operation areas, qualifications, and workflow requirements.

Administrators can configure portal access for the disconnected field applications on both Windows and iOS devices. The pipe inspection report and sub forms can also be modified using the built-in report editor to customize the process as it changes.

SUMMARY

The pipe inspection process is a complicated orchestration of a variety of operations into a streamlined process. Using industry standard software for inspections can help companies, like ETE, build a process that matches business workflows and requirements as opposed to adapting business to technology. The continuous improvement of the process through mobile technologies such as iPhones and iPads has led to wide-scale user acceptance across the organization as well as a continuous feedback channel to improve the overall process. 𝟙



Global Information Systems, LLC specializes in providing innovative workflow solutions to the Pipeline Transmission Industry. Our products and services are designed to help your business become more flexible, integrated, and cost-efficient. Try our data collection, analysis, and management tools today, and lighten your workload.



Project Pulse leverages the power of the GForms® iOS platform to create a simple-to-use application for daily operational documentation that is integrated with advanced dash boarding and reporting functionality. The further inte-gration of Global’s Project Packager™ applica-tion makes Pulse the one-stop, go-to solution for tracking and compliance on projects in the pipeline Right-of-Way.

Pulse is based on a standard project manage-ment hierarchy organized into programs, proj-ects, and lines within a streamlined user inter-faces that provides easy access to project criteria. The Project Pulse portal reporting engine incor-porates intuitive drill-down reporting on each phase of pipeline construction and integrity activities. Track and ensure proper documenta-tion on assessments, corrective actions, remedi-ations, and threat reduction with real-time data from field inspections of pipe, cathodic protec-tion, encroachments, and many more activities.

Project Global’s next generation Web Portal creates a vibrant, data-aware environment where managers and stakeholders can plan, track, visualize, audit and close out pipeline construction and integrity related projects in real time. With Pulse, your company can achieve accurate daily collection of all your pipeline’s activities and track progress via integrated mapping functionality that shows the locations and status of all activities.

Pulse

Utilizing the latest technology, Project Pulse employs a time-tested pipeline construction sequence to track progress through clearing, grading, trenching, stringing, lowering in, back-fill, and restoration. In addition to these custom-ary pipeline construction stages, Pulse collects information and tracks progress on field bends, horizontal directional drilling, bores, road cuts, and tie-ins.

With Pulse, each stage of construction can be visualized through consolidated charting and mapping features; documents can also be uploaded to and associated with specific phases of the project through the integrated Project Packager™ functionality.

Don’t be satisfied with an overall completion guesstimate. With Project Pulse, you know the exact progress of every aspect of your project at any time and you can rest assured that all documentation requirements are complete.

“The ability to work with or without internet access ensures that our projects don’t fall behind schedule. Pulse is an invaluable tool for our organization.”



TheMARCELLUS PLAY

N E W C O N S T R U C T I O N


THE MARCELLUS AND Utica Shale are the largest unconventional gas resource exploration plays in the eastern United States. Extending throughout much of the Appalachian Basin and beyond, these two

regions are now proving vital to the North American quest for energy independence. According to USA Today, with the recent exploration and production (E&P) efforts in the Marcellus-Utica region, the U.S. has even managed to surpass Russia as the world’s largest oil and natural gas producer. Though there is quite a bit of debate over the estimates of recoverable gas—ranging from 84 trillion cubic feet (TCF) to 410 TCF—and we are projected to exhaust the region’s reserves before the end of this century, there is no doubt that the region has proven itself as a crucial and cost-effective alterna-tive to reliance on Middle Eastern oil and gas reserves.

Coupled with other liquid-rich plays across the United States, like Eagle Ford Shale and the Bakken Formation, Marcellus Shale accounted for 27% of U.S. Natural gas production in 2010, and these three plays are expected to account for 43% of production by the end of 2015.

Text by DANIELLE BAXTER

Considering the region’s potential to supplement the nation’s energy supply while keeping commod-ity costs in check, it should come as no surprise that exploration and production companies have wasted little time moving into towns like Washington, PA and the aptly named Point Pleasant formation in eastern Ohio. The influx of E&P companies—like Chesapeake Energy, Range Resources, and EQT—have had consider-able economic impact on the predominantly manufac-turing towns and states in northern and north central Appalachia. Towns like Youngstown, Ohio have wit-nessed manufacturing jobs fall by more than 35% since 2001 alone; yet, with the technological advancements in drilling and the influx of capital, job prospects have increased considerably. In the Ohio region alone, pro-jections estimate that some six-thousand to eight-thou-sand jobs could be created in the near future. And, the job opportunities extend beyond the traditional manu-facturing base for states like Ohio. Governor John Kasich has been consistently optimistic about the shale boom, saying that it could turn the Appalachian corridor that runs through eastern Ohio into “a real economic asset” for the service industry as well. “The people that are here who are working in this industry, they will be down at the ice cream bowl and they will be at the barber-shop and staying in our hotels; so, it could be very good for us.”

There is little disputing the potential economic impact from Appalachia’s shale boom, especially when you consider that more than a billion dollars has already been invested in states like Pennsylvania to improve roads and infrastructure since 2008. Or, that counties in and surrounding shale hotbeds have redirected impact fees to repairing ailing and crucial infrastructure, like bridges. In Pennsylvania’s Montgomery County, more than three million dollars have gone towards bridge repairs alone, while an additional six-hundred million was distributed to local communities in 2013.

Compared to other sources of natural gas, whether imported or located in offshore production wells,



The Marcellus formation is a low density, organic-rich shale that formed from shallow marine deposits in the Appalachian Basin during the Middle Devonian Age, 300 million years ago. This region was uplifted into the mountain range that we recognize today during the Cenozoic Era, 66 million years ago.

the relative proximity of these oil and gas reserves to local communities within the United States and North America is directly correlated to the booms experienced outside of the oil and gas industry itself. According to a recent IHS Global Insight forecast, direct investment in mining, construction, and manufacturing produces jobs that “help sustain indirect and induced manufacturing and service jobs, as well as jobs in retail and wholesale trade.” With an expected three million new jobs added by 2020 and shale salaries in states like Pennsylvania hovering around $90,000, average increases in house-hold incomes across the Marcellus-Utica region are expected to bolster consumer purchasing power and cumulatively increase federal, state, and local govern-ment revenues by $933 billion in the next 20 years.

THE APPALACHIAN REGION AND BEYOND

The potential for this natural gas boom to turn bust is slim. The Appalachian region could contain recov-erable resources equal to almost half of the current proven natural gas reserves in the United States, which means considerable returns for some time, both in terms of natural gas production and economic bene-fits that will continue to accrue to local residents and governments alike. The close proximity of the two plays

to one another is a significant contributing factor in their short- and long-term success. Much of the infra-structure that companies like Range Resources or Chesapeake Energy would need to build in order to drill are already in place. E&P companies benefit from this established infrastructure—as well as the indus-trial history of the region—and its location relative to east coast markets. All of these considerations has lead Range Resources Chairman John Pinkerton to call the Utica a “triple play.” The advantage many of these com-panies see in Upper Devonian and Utica reinvestment is that most of their costs are incremental rather than development of new plays that would occur on a stand-alone basis. Essentially, the Marcellus and Utica regions play off one another in ways that are beneficial to both a broad spectrum of stakeholders as well as seemingly ever-expansive geographic region.

The Marcellus region occupies roughly 170,000 square miles in the north eastern United States, predomi-nantly covering Pennsylvania, West Virginia, Ohio, and New York. Although estimates vary, the Utica shale is a significantly larger reservoir that occupies both the entire Marcellus area and stretches of land further to the North and West. Utica reserves are much deeper than the Marcellus shale—between 3000 and 7000 feet



Unconventional gas refers to any reservoir that has a low permeability necessitat-ing some type of fracturing operation to release gas from the surrounding shale. Historically, these regions have seen low development due to the high cost of gas recovery, but technological advances have resulted in exponential growth in the region. As technology con-tinues to advance, regions like the Marcellus and Utica will play a larger role in sus-taining US energy demands.

below—the reservoir is also significantly older at approximately 50 million years, and it is a much thicker formation.

The term most commonly applied to resources in these regions is unconventional gas, which refers to any reservoir that has a low permeability necessitating some type of fracturing operation to release gas from the surrounding shale in quantities that are commercially viable. Historically, these regions have seen low development due to the high cost of gas recovery; however, technological advances in horizontal drill-ing techniques along with multistage hydraulic fracturing has resulted in expo-nential growth in the region’s production capabilities. As the technology for extract-ing resources from these and other shale plays continues to advance, it is reasonable to believe that regions like Marcellus and Utica will play a larger role in sustaining the energy demands of the United States well into the future.

At current rates of production, the Marcellus

and Utica shale plays account for approxi-mately 6% of the total U.S. natural gas pro-duction and about 20% of the total U.S. gas shale production. The regions are unique due to their vast size and estimated reserves as well as their proximity to the largest con-sumers of gas in the U.S., which are concen-trated in Philadelphia, Boston, and New York City. Even with consumption estimated to increase at a rate close to 14% over the next two decades, the relative expansion of domestic energy sources and the produc-tion of natural gas from shale is expected to reduce dependence on energy imports, down from 24% in 2009 to 18% in 2035.

CRITICAL PIPELINE INFRASTRUCTURE

Exploration and Production companies have been in the region for years, build-ing critical infrastructure to support drill-ing for the production of gas. The advances in drilling technology have made extrac-tion more economical which, in turn, has, in turn, increased the pressure on mid-stream and pipeline companies to build



TOP LEFTFracking depends on facilities that can separate natural gas from the sand, gas, and chemicals used to extract it from shale.

CENTERShale Plays in the Lower 48, showing the Marcellus-Utica region in relation to other stores of natural gas and oil.

infrastructure to support the flow of gas from well to market. In 2010, Kinder Morgan announced plans to construct an underground pipeline capable of trans-porting recovered gas supplies in Western Pennsylvania from West Virginia to Toledo, in order to connect with markets in Michigan and Ontario. Other recent mid-stream production projects have connected Marcellus and Utica gas to markets in New York and New Jersey, with the expectation that greater supplies will ease high gas prices in the Northeast.

Midstream companies are expanding their capabilities in the region through the construction of new pipe-lines and processing facilities to support the increases in development. New regulated and unregulated gath-ering line infrastructure is being added to transport gas from the well to processing facilities, and eventually to market. Processing facilities, or Cryogenic Plants, are being built to remove the dissolved petroleum liquids found in the wet gas of the region before it can be shipped to market. Existing transmission pipeline and E&P companies are strategically evaluating their assets to determine potential future uses. Many E&P compa-nies in the U.S. have been producing gas to send to the Northeast region, while other long-haul pipeline companies networks have been designed to ship prod-ucts within the same region. Historically, transmission pipelines from the West and southern regions of the U.S. have accounted for 85% of the gas utilized in the Northeast. In 2011, that ratio had already dropped to 65%, largely due to Marcellus and Utica production, which has encouraged pipeline operators to explore methods of backhauling gas out of the region as the U.S. looks to become a net exporter of gas.

FUTURE PROJECTIONS

The current production volume from the Marcellus shale is small compared to the potential reserves. According to the Pennsylvania Department of Environmental Production, production from the state’s portion of the Marcellus shale has increased to 4.4 billion cubic feet per day in 2012, up from 0.5 bcf/d in 2009. These dra-matic increases are having positive economic benefits throughout the region. Additionally, the dry and wet gas is producing higher rates of return for the region due to the lower exploration, development, and production costs as compared to similar shale plays throughout the U.S. In 2009, for the state of Pennsylvania, the direct economic impact to the area was estimated at 1.9 billion

dollars, with an indirect impact of 828 million dollars. As the rate of production exponentially increases in the region, the economic benefits should follow.

Although much of the emphasis is exploration and pro-duction in the Marcellus and Utica regions, a significant amount of money is also spent in preparation for con-struction and in post-construction management. Along with the ongoing operation of new infrastructure, other key economic sectors benefit from the Marcellus and Utica shale plays, some of which are outlined on the left.

TECHNOLOGY’S ROLE IN THE PLAY

The key to developing unconventional basins has been the significant improvements in technology. Advancements in seismology, drilling, and well stim-ulation have transformed the ability for wells in the region to produce commercial amounts of gas eco-nomically. As these technologies continue to improve and allow companies to drill deeper, and with more accuracy, additional advancements are being made through innovative uses of information technology that are changing productivity and management of the entire region. Using Geographic Information Systems to model assets helps companies to identify better well sites while also being capable of better land manage-ment, leasing, and mineral rights ownership. Artificial intelligence systems are being used to monitor and adjust production wells remotely—without human intervention—based on terabytes of data. Even the construction management process has been revolu-tionized through the use of technology. Pipeline con-struction projects can be managed in real time, using mobile devices and smart forms to track stages of con-struction, while project managers monitor progress remotely. The pace of technological advancement is improving rapidly and is seen as the driving factor in the success of the Marcellus and Utica shale plays. The exponential growth in the region is a testament to the ability of innovative companies to safely and economi-cally develop this region well into the future. 𝟙

Danielle Baxter is the Marketing Coordinator for Global Information Systems. She is responsible for the production and review of Global’s communications strategy, adver-tising materials, and marketing collateral.



MARCELLUS IMPACT

The Marcellus and Utica regions impact

multiple industries beyond oil and gas.

Mining

Utilities

Construction

Manufacturing

Wholesale Trading

Retail Trade

Professional Services

Transportation

Warehousing

Real-Estate

Health & Social Services

Hotel & Food Services

Government

Technical & Scientific Services

IN·TEG·RI·TY

When you need the best field technicians in the industry, turn to Streamlined Field Services. Our employees are professionally trained experts, and we utilize the latest mobile technologies to gather, process, and store your asset data so that you can expect the best results every time.



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