north american oil & gas pipelines · has announced plans to build two new pipelines over the...

4 North American Oil & Gas Pipelines | AUGUST 2013 napipelines.com

26Canadian Natural Gas Pipeline ReportA survey of natural gas pipeline projects in Canada for 2013 and beyond.By Bradley Kramer

30Supplying the ShaleEquipment dealers address the needs and challenges of supplying shale energy production.By Shane Sirmons

34Responsible FrackingEcologix bridges environmental concerns associated with water use in hydraulic fracturing operations. By Eli Gruber

38Monumental Pipeline JourneyThree trenchless bores help deliver energy to Missouri’s Lake of the Ozarks.By Randy Happel

August 2013Volume 6 Issue 8Published by Benjamin Media Inc.

North American Oil & Gas Pipelines (ISSN 2166-6334) is published twelve times per year. Copyright 2013, Benjamin Media Inc., 10050 Brecksville Rd., Brecksville, OH 44141 USA All rights reserved. No part of this publication may be reproduced or transmitted by any means without written permis-sion from the publisher. One year subscription rates: complimentary in the United States, Canada and Mexico. Single copy rate: $10. Subscriptions and classified advertising should be addressed to the Brecksville office. Periodicals Postage paid at Cleveland, Ohio and at additional mailing offices. POSTMASTER: send Changes of Address to North American Oil & Gas Pipelines, 10050 Brecksville Road, Brecksville, OH 44141 USA.

Canadian Subscriptions: Canada Post Agreement Number 7178957. Send change address information and blocks of undeliverable copies to Canada Express; 7686 Kimble Street, Units 21 & 22, Mississauga, ON L5S 1E9 Canada

North American Oil & Gas Pipelines Magazine is not affiliated or associated with North American Pipe Corporation of Houston, Texas.

DEPARTMENTS 8 News

14 Project Roundup

42 Product Showcase

46 Calendar

COLUMNS 6 Editor’s Message

MARKETPLACE

45 Business Cards

46 Index of Advertisers

ON ThE COvER: Track-driven crawler carriers provide accessibility to the most challenging jobsites. When terrain would cause wheeled machinery to get stuck in the muck, these versatile machines can get in and get the job done.

20 Carrying the Load Multitasking crawler carriers serve the pipeline industry in a variety of capacities.By Bradley Kramer

FEATURES

6 North American Oil & Gas Pipelines | AUGUST 2013

Oil and Gas Fueling Jobs Growth As creating jobs continues to be a major concern in North America, the oil and

gas sector stands out as a shining example for growth. A recent study commissioned by the American Petroleum Institute (API) reported

that the oil and gas industry supported a total of 9.8 million U.S. jobs in 2011, including more than 600,000 jobs created in just two years. While many states still struggle with high unemployment, energy producing states like North Dakota and Texas are experiencing job growth.

Citing data from the U.S. Labor Department’s Bureau of Labor Statistics, the Energy Information Administration (EIA) reported on Aug. 8 that jobs in the oil and natural gas industry increased by more than 162,000 — a 40 percent jump — from the start of 2007 through the end of 2012. During the same period, statistics showed private sector employment grew by 1 million jobs or by 1 percent.

The Bureau of Labor Statistics accounts for oil and natural gas industry employment in three categories: drilling, extraction and support. According to the EIA report, drilling accounted for more than 90,000 jobs by the end of 2012, an increase of 6,600 jobs since 2007; extraction accounted for more than 193,000 jobs by the end of 2012, 53,000 more jobs than in 2007; and support (the largest oil and gas industry category) accounted for more than 286,000 people by the end of 2012, up more than 102,000 jobs from 2007.

Meanwhile, President Barack Obama claims the Keystone XL project would not be a “big jobs generator.” In a July 27 interview with the New York Times, the president dismissed the number of estimated jobs the project would create.

“My hope would be that any reporter who is looking at the facts would take the time to confirm that the most realistic estimates are this might create maybe 2,000 jobs during the construction of the pipeline — which might take a year or two — and then after that we’re talking about somewhere between 50 and 100 jobs in an economy of 150 million working people,” Obama told the Times.

His own State Department refutes those numbers in its Draft Supplemental Environmental Impact Statement, released in March, which estimated that the Keystone XL would require about 10,000 construction jobs in four- to eight-month seasonal construction periods (5,000 to 6,000 per construction period). “When expressed as average annual employment, this equates to approximately 3,900 jobs,” the statement reports.

While we continue to wait on the Keystone XL, the Energy and Commerce Committee in the U.S. House of Representatives has proposed a measure to speed up the Federal Energy Regulatory Committee (FERC) approval process for natural gas pipeline projects. The Natural Gas Pipeline Permitting Reform Act would require FERC to approve or deny projects within 12 months of application. As shale drilling and exploration continues to ramp up, this bill could help improve infrastructure expansion and thereby create even more jobs in the oil and gas sector.

Brad KramerManaging [email protected]

Editor’s Message PUBLISHER

Bernard P. [email protected]

EDITORIALEditor: James W. [email protected]

Managing Editor: Brad [email protected]

Contributing Staff Editors:Sharon Bueno • Andrew FarrKeith Gribbins • Pam Kleineke • Kelly Pickerel

SALES+MARKETINGMarketing Director: Kelly [email protected]

Regional Sales Manager: Ryan [email protected]

Conferences Manager: Melanie [email protected]

Conferences Sales Coordinator: Brittany [email protected]

PRODUCTION+FULLFILLMENTProduction Manager: Chris [email protected]

Graphic ArtistsSarah HaughawoutDeb McManus • Elizabeth Stull

Web/Interactive Manager: Mark [email protected]

Audience Development Manager: Alexis R. [email protected]

Circulation & Fullfillment Coordinator: Lillian [email protected]

REPRINTS Wright’s Media Ph: (877) 652-5295 • Fax: (281) 419-5712

EDITORIAL ADvISORy BOARD Cortez Perotte Pipeline Product Engineer/Industry Representative, Caterpillar Inc.

Todd Porter Vice President of Business Development, New Century Software Inc.

Brian RohwerSafety Manager, Northern Gateway Project, Enbridge Pipelines Major Projects

Eric Skonberg Principal Engineer, Trenchless Engineering Corp.

Don W. Thorn President, Welded Construction LP

Kevin Waschuk Vice President, Waschuk Pipe Line Construction Ltd.

Bob Westphal Senior Strategic Advisor, Michels Corp.

Chief Executive Officer: Bernard P. [email protected]

President: Robert Krzys [email protected]

Controller: Marianne [email protected]

10050 Brecksville Rd.Brecksville, OH 44141 USA (330) 467-7588 • Fax: (330) 468-2289 www.napipelines.com [email protected]

NorthAmerican Oil & Gas


North America News

As the pipeline industry awaits a deci-sion on the Keystone XL project, Trans-Canada continues to push ahead with plans to expand its oil and gas infrastruc-ture in North America. The company has announced plans to build two new pipelines over the next five years, one to bring crude oil eastward from the Cana-dian oil sands in the west and another to expand natural gas capacity in northeast-ern British Columbia.

After a successful open season gar-nered strong support, TransCanada announced on Aug. 1 that it would proceed with the 1.1 million barrel per day (bpd) Energy East Pipeline. The company secured binding, long-term contracts for 900,000 bpd to transport crude oil from western Canada to east-ern Canadian refineries and export ter-minals. The project is estimated to cost $12 billion (CAD) and expected to be in service by late 2017.

TransCanada announced on Aug. 6 that its subsidiary NOVA Gas Transmission Ltd. (NGTL) has signed agreements with Progress Energy Canada Ltd. for approximately 2 billion cubic feet per day (bcf/d) of firm gas transportation services to underpin the development of a major pipeline extension of the NGTL System. The North Montney Mainline extension will provide additional capacity in response to on increased development of natural gas resources in northeastern British Columbia. The project is estimated to cost $1.5 billion and to be in service by the beginning of 2019.

Both projects still need to complete the regulatory process to move forward.

Going Back EastThe Energy East Pipeline project in-

volves converting a portion of natural gas pipeline capacity in approximately 3,000 km (1,864 miles) of TransCan-ada’s existing Canadian Mainline to crude oil service and constructing ap-proximately 1,400 km (870 miles) of new pipeline. The pipeline will trans-port crude oil from receipt points in

Alberta and Saskatchewan to delivery points in Montreal, the Québec City region and Saint John, New Brunswick. The pipeline will terminate at Canaport in Saint John, where TransCanada and Irving Oil have formed a joint venture to build, own and operate a new deep water marine terminal.

“We are very pleased with the outcome of the open sea-son for the Energy East Pipe-line held earlier this year and are excited to move forward with a major project that will bring many benefits across Canada,” said Russ Girling, TransCanada’s president and

Keystone Delays Don’t Stop Other TransCanada ProjectsCompany to Proceed Developing Two Pipelines to Serve Canadians

No Keystone XL? No problem. The Energy East Pipeline (above) and the North Montney Mainline extension (right) projects represent TransCanada’s continued expansion of oil and gas transmission infrastructure.

napipelines.com AUGUST 2013 | North American Oil & Gas Pipelines 9

CEO. “This is an historic opportunity to connect the oil resources of western Canada to the consumers of eastern Canada, creating jobs, tax revenue and en-ergy security for all Canadians for decades to come.”

Girling added that interest in Energy East supports refineries’ desire to have access to a stable and reliable supply of western Canadian crude oil — pushing out more expensive crude oil from foreign regimes. Eastern Canada currently imports approximately 700,000 bpd. It also confirms the desire producers have to support safe and innovative ways to get their crude oil to market.

“Energy East is one solution for transporting crude oil but the industry also requires additional pipelines such as Keystone XL to transport growing supplies of Canadian and U.S. crude oil to existing North American markets,” Girling said. “Both pipelines are required to meet the need for safe and reliable pipe-line infrastructure and are underpinned with bind-ing, long-term agreements.”

The project is expected to cost approximately $12 billion, excluding the transfer value of Canadian Mainline natural gas assets. The Energy East Pipeline will have a capacity of approximately 1.1 million bpd and is anticipated to be in service by late 2017 for deliveries in Québec and 2018 for deliveries to New Brunswick.

While Energy East will use a portion of Canadian Mainline capacity, TransCanada is committed to con-tinuing to meet the needs of its gas customers in eastern Canada and the northeastern United States. Construc-tion is expected to begin in early 2014.

Invest in the WestThe proposed North Montney Mainline project

will be a large diameter extension from the existing Groundbirch Mainline section of the NGTL system in northeastern British Columbia. It will consist of two sections, Aitken Creek and Kahta, totaling ap-proximately 305 km (189 miles) in length, and will include associated metering facilities, valve sites and possible compression facilities. The project will also include an interconnection with Trans-Canada’s proposed Prince Rupert Gas Transmission (PRGT) project to provide natural gas supply to the proposed Pacific NorthWest LNG export facility near Prince Rupert, British Columbia.

Under the commercial arrangements with Progress Energy, receipt volumes will ramp up between 2016 and 2019 to an aggregate volume of approximately 2 bcf/d and delivery volumes to the PRGT project will be approximately 2.1 bcf/d beginning in 2019. NGTL is also in discussions with other parties that have ex-pressed interest in obtaining transportation services that would use the North Montney Mainline facili-ties. The total cost for the North Montney Mainline project is estimated to be approximately $1.5 billion.

NGTL is continuing to advance its development work on the project, including field studies, engineer-ing and design work, and pipeline routing to support applications for regulatory approvals and finalize proj-ect requirements. First Nations, landowner and com-munity engagement and consultation activities for the North Montney Mainline project have commenced.

“The initial work for the project is proceeding well and we anticipate filing an application with

the National Energy Board in the fourth quarter of 2013 for ap-provals to build and operate the facilities,” said Karl Johannson, TransCanada’s executive vice president and president, Natural Gas Pipelines. “If we receive the necessary approvals, we expect the Aitken Creek section to be operational in second quarter 2016, the Kahta section in second quarter 2017 and the export delivery facilities in 2019.”

Trenchers and Equipment Inc. (TEI) has released a new entry in its stable of rugged wheel trenchers, the Eagle 7500. The company released the first Eagle Wheel Trencher in 1988, the model 4500. Now, nine models are available for underground construction applications such as pipeline construction.

The Eagle 7500 Wheel Trencher boasts a Cat Tier 3 diesel engine that packs 250 hp and features electronically controlled hydraulic drives, GPS compatibility, 7-ft digging depth, 24- to 36-in. cutting widths and weighing in at 56,000 lbs.

“Wheel trenchers provide the fastest method of open cut excavation,” said Michael Ellingson, president of Trenchers and Equipment. “One Eagle Wheel Trencher can replace anywhere from four to 10 backhoes. Trenchers also leave behind a perfect trench with a fine spoil that can be discharged to either side of the machine or loaded directly onto a truck.”

TEI has been involved with the design and manufacture of wheel trenchers for more 53 years and has machines working on jobsites around the world. Eagle Wheel Trenchers are designed and built at the company’s facilities in Ripon, Calif.


HSB Solomon Associates Acquires Ziff Energy Group

HSB Solomon Associates, a leading performance improvement company for the global energy industry, has acquired Ziff Energy Group, an international energy consulting firm. The transaction adds global energy exploration and production benchmarking and North American natural gas forecasting to Solomon’s suite of products and services.

“Solomon and Ziff Energy share similar cultures and a focus on helping clients achieve excellence through the measurement and analysis of opera-tional performance,” said Greg Barats, president and CEO of Hartford Steam Boiler, part of Munich Re and chair-man of HSB Solomon Associates. “We can now deliver a full range of bench-marking and consulting services across the entire oil and gas supply chain for the world’s largest energy providers.”

The terms of the transaction were not disclosed.

Ziff Energy, with offices in Calgary and Houston, focuses principally in two areas: exploration and produc-tion studies across 40 countries cov-ering more than 4,300 production fields and gas services in North Amer-ica. Its gas services include in-depth analysis of North American and re-gional markets, gas and liquids sup-ply, transportation, midstream, stor-age, regulatory affairs and long-term gas pricing forecasts.

“Over the past 30 years Ziff Energy has established itself as a leader in energy exploration and production benchmarking and outlook services for the North American natural gas market,” said Paul H. Ziff, CEO of Ziff Energy. “By combining with Solomon we can further expand our offerings geographically and develop new ser-vices for our clients.”

With the acquisition HSB Solomon Associates now offers benchmarking services for exploration and produc-tion, natural gas, pipelines and termi-nals, refining, chemicals and power generation, as well as consulting ser-vices across each of these energy in-dustry segments.

Williams Seeks FERC Approval to Expand Natural Gas Service

Williams Partners LP is seeking fed-eral approval to expand its natural gas facilities in the U.S. Southeast. The company’s Transco natural gas pipe-line has filed an application with the Federal Energy Regulatory Commis-sion (FERC) to expand a compressor station and provide additional firm natural gas transportation capacity to growing markets in the region by the spring of 2015.

The Mobile Bay South III Expan-sion Project is designed to provide 225,000 dekatherms (or about 2.18 billing cubic feet) per day of firm transportation service on the Trans-

co Mobile Bay Lateral from the Sta-tion 85 4A Pooling Point and other receipt points located at Transco’s Station 85 in Choctaw County, Ala., to interconnections with Florida Gas Transmission and Bay Gas Storage in Mobile County, Ala. The project would deliver enough natural gas to provide service to approximately 1 million homes.

“Growing power-generation de-mand has dramatically increased utilization of Transco’s Mobile Bay Lateral in recent years,” said Frank Fe-razzi, general manager of the Transco system. “Our proposed Mobile Bay South III expansion is an efficient way to move additional supply from a well-positioned compressor station in Choctaw County, Ala. to a number of regional storage facilities to growing Southeastern markets.”

The proposed expansion would involve adding compression power at Transco Compressor Station 85, along with upgrades at existing fa-cilities in Washington and Mobile counties in Alabama. With FERC ap-proval, construction could begin in the spring of 2014. The capital cost of the project is estimated to be ap-proximately $50 million.

The 10,200-mile Transco pipeline provides natural gas transportation and storage services for markets throughout the northeastern and southeastern United States. Ma-jor markets include New York City, Philadelphia, Washington, D.C., and Atlanta.

Trenchers and Equipment Inc. Releases New Wheel Trencher

U.S. Energy Department Launches Initiative to Strengthen Cyber Security

U.S. Energy Secretary Ernest Moniz announced in June a public-private partnership to strengthen protection of the nation’s oil and natural gas in-frastructure from cyber attacks. Led by the Department of Energy and in collaboration with industry experts, the Department of Homeland Secu-rity and other stakeholders, the ini-tiative will create a tool that allows owners and operators to assess their cyber security capabilities and priori-tize their actions and investments to improve cyber security.

“As cyber threats continue to in-crease in frequency and sophistica-tion, helping critical infrastructure owners and operators across the en-ergy sector identify opportunities to strengthen their own cyber security capabilities is a top priority,” Moniz said. “Building on the successes in the electricity industry, this initia-tive for the oil and gas sector is an important step in moving us closer to achieving the department’s vision of resilient energy delivery systems that can survive a cyber incident while sustaining critical functions.”

Officials from the DOE, the White House, Homeland Security, other federal agencies, Carnegie Mellon University’s Software Engineering Institute and the Oil & Natural Gas Sector Coordinating Council met on June 27 with representatives from the sector to launch this initiative. Over the next several months, the DOE will host a series of meetings during which the initiative’s par-ticipants will collaborate to create a draft maturity model. More than a dozen owners and operators are expected to participate in a subse-quent pilot program that will assess the maturity model’s effectiveness and validate results. Following the pilot, the model will be updated and released to the industry.

The new Oil and Natural Gas Cybersecurity Capability Maturity Model (ONG-C2M2) will leverage the Electricity Subsector Cybersecu-rity Capability Maturity Model (ES-C2M2). The ES-C2M2 tool was de-veloped last year as part of a White House initiative to support the private sector and utilities to deter-

mine their current cyber security re-sources and identify additional steps to help strengthen their defenses. The ES-C2M2 is now used across the electricity industry.

Maturity models, which rely on best practices to identify an organization’s strengths and weaknesses, are widely used by other sectors to improve performance, efficiency and quality. When the ONG-C2M2 is completed it will be used by the oil and natural gas sector to offer critical benefits to help identify the unique strengths and weaknesses of the industry.

American Augers Names Director of Product Management

A m e r i c a n Augers has an-nounced the ap-pointment of Richard Levings to the position of Director of Prod-uct Management. Levings will repre-sent not only American Augers prod-ucts but the newly acquired Trencor line. Equipment included under his direction is auger boring machines, mid-size directional drills, maxi-rigs, mud pumps and cleaning systems, tooling, accessories, trenchers and surface miners.

He will be responsible for work-ing with end users to ensure future product designs and modifications meet the needs of the ever-changing underground market.

Levings has been part of The Charles Machine Works Inc. (CMW) for the past 23 years, serving 18 of those as the trenchless product manager for the Ditch Witch brand responsible for developing the Ditch Witch HDD product line. In order to continue the CMW tradi-tion of being the Underground Au-thority, Levings was appointed this position in Ohio to leverage prod-uct development throughout the CMW brands.

While serving on numerous un-derground organization committees, Levings remains a trenchless indus-try advocate by speaking around the globe at trade shows and educational seminars. He resides in Perry, Okla-homa and is a graduate of Oklahoma State University in Stillwater, Okla.


New Data Shows Growth in U.S. Crude Oil, Natural Gas Reserves

U.S. proved crude oil reserve additions in 2011 set a record volumetric increase for the second year in a row, accord-ing to “U.S. Crude Oil and Natural Gas Proved Reserves, 2011” report recently released by the U.S. Energy Information Administration (EIA). Natural gas proved reserves also rose, but by less than 2010’s record increase. Nevertheless, natural gas reserve additions in 2011 rank as the sec-ond largest annual increase since 1977.

“Horizontal drilling and hydraulic fracturing in shale and other tight rock formations continued to increase oil and natural gas reserves,” said EIA ad-ministrator Adam Sieminski. “Higher oil prices helped drive record increases in crude oil reserves, while natural gas reserves grew strongly despite slightly lower natural gas prices in 2011.”

Proved oil reserves, including both crude oil and lease condensate, increased by 15 percent in 2011 to 29 billion bar-rels, marking the third consecutive an-nual increase and the highest volume of proved reserves since 1985. Proved

reserves in tight oil plays accounted for 3.6 billion barrels (13 percent) of total proved reserves of crude oil and lease condensate in 2011.

Texas recorded the largest volumetric increase in proved oil reserves among individual states, largely because of con-tinuing development in the Permian and Western Gulf basins, while North Dakota had the second largest increase, driven by development activity in the Bakken for-mation in the Williston Basin.

Natural gas proved reserves, estimat-ed as wet gas that includes natural gas liquids, increased by almost 10 percent in 2010 to 348.8 trillion cubic feet (tcf), the 13th consecutive annual increase.

Pennsylvania’s proved natural gas re-serves, which more than doubled in 2010, rose an additional 90 percent in 2011, contributing 41 percent of the overall U.S. increase. Combined, Texas and Pennsylva-nia added 73 percent of the net increase in U.S. proved wet natural gas reserves in 2011. Proved reserves in shale gas plays accounted for 131.6 trillion cubic feet (38 percent) of total proved reserves of wet natural gas in 2011.

Proved reserves are those volumes of oil and natural gas that geological and engineering data demonstrate with rea-

sonable certainty to be recoverable in fu-ture years from known reservoirs under existing economic and operating condi-tions. EIA’s estimates of proved reserves are based on an annual survey of about 1,100 domestic oil and gas well operators.

Terry Flynn Joins Tulsa Rig Iron

Tulsa Rig Iron has hired industry vet-eran Terry Flynn as part of the company’s business develop-ment team.

Flynn most recent-ly served as execu-tive sales manager for corporate accounts at Vacuworx Global, where he was instrumental in the de-velopment of the annual Tulsa Pipeline Expo. Flynn’s expertise includes sales, marketing and event planning. He is actively involved in The Pipe Liners Club of Tulsa, along with many other industry trade associations.

Tulsa Rig Iron specializes in the en-gineering and manufacturing of mud pumps, mud recycling systems and as-sociated equipment.


Pemex Facing Illegal Pipeline Taps

The Associated Press reported that the number of illegal taps drilled into Mexican oil and gas pipelines to steal fuel has doubled so far in 2013. The report indicates that there may be a thriving industry based on selling stolen fuel in Mexico and possibly ex-porting it.

Petroleos Mexicanos (Pemex), Mexi-co’s state-owned oil company, discov-ered 1,421 illegal fuel taps in the first six months of this year, which is al-most twice the 722 taps found in the same period of 2012.

According to the report, thieves stole the equivalent of 2.7 million barrels of fuel, equal to more than one day of the company’s annual oil output. The company has estimated that such thefts cost it about $5 bil-lion a year.

Furthermore, the illegal fuel taps fre-quently result in explosions or fires, such as a recent pipeline explosion that injured seven people on the outskirts of Mexico City. One attempted theft caused an explosion that killed 29 peo-ple in December 2010.

Willbros Names New Senior Vice President

Willbros Group Inc. has promoted Mike Futch from vice president and general manager of Willbros Construction to se-nior vice president of regional and integrity construction.

Futch will be responsible for providing leadership and direction to the Northeast and Southeast Regional business units, coupled with strategic planning and ex-ecution of a fully integrated service line targeting integrity construction. Integrity construction efforts will be spread across North America and geared primarily to-ward assisting customers in the pipeline industry as they develop compliance so-lutions for the Pipeline Safety, Regulatory Certainty and Job Creation Act of 2011.

Futch has more than 16 years of experience in the pipeline industry. He joined Willbros in August 2012 as director of engineering and was pro-moted to vice president and general manager in November 2012. Prior to his promotion, he was responsible for the successful execution of two major

projects in the Utica shale formation. Futch has extensive industry man-

agement experience in the operations, engineering and project management disciplines. He joined Willbros from NiSource Gas Transmission & Storage where he served as pipeline engineer-ing manager. While with NiSource, he was responsible for providing engineer-ing technical support to operations and projects. He also represented NiSource in Pipeline Research Council Interna-tional (PRCI) and International Natural Gas Association of America (INGAA) initiatives geared toward advancing pipeline design, operating and mainte-nance standards, integrity management programs, federal regulations for pipe-line safety and industry best practices. He has also held management positions with Continental Energy Services and Southern Union’s Panhandle Energy.

“Mike’s industry experience, leader-ship and project management skills are exactly what we need to help manage our regional business and take our integ-rity construction offering to a new level,” said Earl Collins, president of Willbros’ oil and gas segment. “He is an integral member of this organization and his tal-ent certainly gives us an edge over our competitors.”


North American Pipeline Project Roundup

Listings Contributed by

The following oil and gas pipeline projects have been announced. Projects are in order of most recent approxi-mate starting date. All projects are for 2013 unless noted.

Northern Clearing Inc. was awarded a contract by Michels Corp. for the clearing of approximately 144 miles of 36-in. pipeline right of way in Livingston, Woodford, Tazewell, Mason, Fulton, Schuyler, Brown and Adams counties, Ill. Headquarters is unknown. The superintendent is Daniel Vernon. Approximate start date: Aug. 8.

Northern Clearing Inc. was awarded a contract by U.S. Pipeline Inc. for the clearing of approximately 153 miles of 36-in. pipeline right of way in Allen, Wilson, Montgomery and Chautauqua counties, Kan., and Washington, Osage, Pawnee, Payne and Lincoln counties, Okla. Headquarters is unknown. The superintendent is Rod Grubisic. Approxi-mate start date: Aug. 7.

Northern Clearing Inc. was awarded a contract by U.S. Pipeline Inc. for the clearing of approximately 149 miles of 36-in. pipeline right of way in Saline, Lafayette, Johnson, Cass and Bates counties, Mo., and Linn and Allen counties, Kan. Headquarters is unknown. The superintendent is Jim Junker Jr. Approximate start date: Aug. 7.

InfraSource LLC was awarded a contract by Enterprise Products for integrity digs, including welding of sleeves, on various size pipelines in Clearfield, Elk, Cameron and Potter counties, Pa. Headquarters is Cambridge, Ohio. The superintendent is Kirby Niebaum. Approximate start date: Aug. 5.

Utility Services Authority LLC was awarded a contract by C.J. Hughes Pipeline for the installation of approximately 2,200 ft of 10-in. pipeline via directional drilling in Pike County, Ky. Headquarters is Gulnare, Ky. The superintendent is Casey Sarkozi. Approximate start date: Aug. 5.

Midwest Underground Inc. was awarded a contract by Northern Natural Gas for the installation of approximately 10 miles of 2-in. pipeline in Butler, Seward and Gage counties, Neb. Headquarters is unknown. The superintendent is Shaun Tippie. Approximate start date: Aug. 1.

Price Gregory International Inc. was awarded a con-tract by Enterprise Products for the installation of approxi-mately 97 miles of 16-in. pipeline and 19.2 miles of 20-in. pipeline in Sandoval, Bernalillo, Santa Fe, Torrance, Gua-dalupe, Lincoln, De Baca, Chaves and Lea counties, N.M. Headquarters is unknown. The superintendent is Mike Phillips. Approximate start date: Aug. 1.

Pipeline Energy Group Inc. (d/b/a Carl Smith Pipeline) was awarded a contract by Mark West for various 6-in. pipeline station work in Wetzel County, W.Va. Headquar-ters is West Union, W.Va. The superintendent is Eddie Smith. Approximate start date: August 2013 (an-nounced July 22).

Minnesota Ltd. LLC was awarded a contract by Co-lumbia Pipeline Group for the installation of a temporary separator with associated piping and the cleaning of 26- and 36-in. pipelines in Kanawha, Clay, Braxton, Upshur, Randolph, Pendleton and Hardy counties, W.Va. Head-quarters is Clendenin, W.Va. The superintendent is Tim Dunn. Approximate start date: July 30.

Foltz Welding Ltd. was awarded a contract by Marathon Pipeline for the nitrogen purge of approximately 400 miles of 26-in. pipeline from Beaumont, Texas, to Longville, La., and the installation of approximately 400 ft of 4- and 6-in. pipelines in Longville, La., and Tutwiler and Fisherville, Miss. Headquarters is unknown. The superintendent is Rich Torrence. Approximate start date: July 29.

Laney Directional Drilling Co. was awarded a contract by ExxonMobil Pipeline Co. for the installation of approxi-mately 1,061 ft of 8-in. pipeline in Brazoria County, Texas. Headquarters is on the jobsite. The superintendent is Jerry Cordova. Approximate start date: July 29.

Laney Directional Drilling Co. was awarded a contract by Sheehan Pipe Line Construction Co. for the installation of approximately 1,644 ft of 42-in. pipeline via directional drilling in Jackson Parish, La. Headquarters is on the job-site. The superintendent is Jimmy Johnson. Approximate start date: July 29.

Appalachian Pipeline Contractors LLP was awarded a contract by Williams Northwest Pipeline Group to take up approximately 18,500 ft of 10-in. pipeline and lay approximately 18,500 ft of new 16-in. natural gas pipe-line in King County, Wash. Headquarters is unknown. The superintendent is Bobby Rose. Approximate start date: July 25.

Pete Gould & Sons Inc. was awarded a contract by Domin-ion Peoples/Mascaro to install 6.5 miles of 20-in. steel pipe-line in Johnstown, Pa. Approximate start date: July 25.

CBC Pipeline LLC was awarded a contract by Mark West Energy for the installation of approximately 9.52 miles of various lengths of 2- to 20-in. pipelines in Harrison County, Ohio. Headquarters is Cadiz, Ohio. The superintendent is Mark Elliott. Approximate start date: July 24.




Dun Transportation & Stringing Inc. was awarded a contract by Welspun/TransCanada to offload and stockpile approximately 50 miles of 36-in. pipe in Liberty County, Texas. Headquarters is the pipe yard. The superintendent is John Denton. Approximate start date: July 24.

Price Gregory International Inc. was awarded a con-tract by Dominion Transmission Inc. for rehabilitation work on approximately 17.36 miles of 6- to 30-in. pipelines in Armstrong, Beaver, Butler, Ind., and Westmoreland coun-ties, Pa. Headquarters is Darlington, Pa. The superinten-dent is Doug Gregory. Approximate start date: July 24.

Precision Pipeline LLC was awarded a contract by Access Midstream for the installation of approximately 23 miles of 6-, 8-, 10- and 12-in. pipeline in Greene County, Pa. Headquarters is Triadelphia, W.Va. The superintendent is Mark Wright. Approximate start date: July 22.

Utility Services Authority LLC was awarded a contract by R.L. Coolsaet Construction Co. for the installation of approximately 3,800 ft of 12-in. pipeline via directional drilling at eight locations in Franklin County, Ohio. Headquarters is unknown. The superintendent is Casey Sarkozi. Approximate start date: July 22.

Dun Transportation & Stringing Inc. was awarded a contract by Enterprise to unload and stockpile approximately 20 miles of 16-in. pipe m Cook County, Ill. Headquarters is the pipe yard. The superintendent is Johnny Denton. Approximate start date: July 19.

Pedero Pipe Support Systems USA was awarded a contract by Michels Corp. to spray foam breakers on 4 miles of 30-in. pipeline in Potter County, Pa. Headquarters is Coudersport, Pa. The superintendent is Kirk Baker. Approximate start date: July 16.

InfraSource Construction LLC was awarded a contract by Enbridge for various pipeline integrity digs throughout southern Wisconsin. Headquarters is Portage, Wis. The superintendent is Chris Powell. Approximate start date: July 15.

Midwest Underground Inc. was awarded a contract by Kinder Morgan for the hydrotesting of 1 mile of 16-in. pipeline in Bureau County, Ill. Headquarters is unknown. The superintendent is Jeff Thomason. Approximate start date: July 15.

Pe Ben USA Inc. was awarded a contract by TransCanada Pipeline Co. to build a storage yard for 48 miles of 36-in. pipe in Chambers County, Texas. Headquarters is Rushville, Ill. The superintendent is Robert Doven. Approximate start date: July 15.

Sheehan Pipe Line Construction Co. was awarded a contract by CenterPoint Energy for the installation of 1,750 ft of 42-in. pipeline via directional drilling in Jackson Parish, La. Headquarters is Hodge, La. The superintendent is Thelbert Barnes. Approximate start date: July 15.

Snelson Cos. Inc. was awarded a contract by Enterprise Products Partners LP for the installation of 49.6 miles of 16-in. pipeline in Utah and 45.9 miles of 16-in. pipeline in Colorado in two spreads: Spread 1 is 78 miles in Garfield and Mesa counties, Colo., and Grand County, Utah; Spread 2 is 17.5 miles in Uintah County, Utah, and Rio Blanco County, Colo. Headquarters for Spread 1 is Fruita, Colo. Headquarters for Spread 2 is Rangely, Colo. The superintendent for Spread 1 is Keith Maxwell. The superintendent for Spread 2 is Don Cupit. Approximate start date: July 15 (for both spreads).

Snelson Cos. Inc. was awarded a contract by Pacific Gas & Electric for the installation of 3.5 miles of 24-in. pipeline in Fresno County, Calif. Headquarters is unknown. The superintendent is Mark Zogg. Approximate start date: July 15.

Supreme Industries was awarded a contract by Price Gregory International Inc. for the clearing of 14.5 miles of 6-, 8- and 16-in. pipeline rights of way in Sullivan County, Pa. Headquarters is Dushore, Pa. The superintendent is Scott Thibodeau. Approximate start date: July 15.

U.S. Pipeline Inc. was awarded a contract by Dominion Transmission for the installation of approximately 9,200 ft of 24-in. pipeline and removal of a retired 24-in. pipeline in Prince William County, Va. Headquarters is Bristow, Va. The superintendent is Tommy Dunn. Approximate start date: July 15.

CBC Pipeline LLC was awarded a contract by Mark West Energy for the installation of 4.3 miles of 20-in. pipeline and 1 mile of 20-in. pipeline in Guernsey and Harrison counties, Ohio. Headquarters is Cadiz, Ohio. The superintendent is Mark Elliott. Approximate start date: July 11.

Henkels & McCoy Inc. was awarded a contract by Columbia Gas for the installation of approximately 4 miles of 8-in. pipeline in York County, Pa. Headquarters is Hanover, Pa. The superintendent is Ed Murphy. Approximate start date: July 10.

InterCon Construction Inc. was awarded a contract by Integrity Pipeline for the installation of 20- and 22-in. pipeline via directional drilling in Ritchie, Pleasants and Tyler counties, W.Va. Headquarters is unknown. The superintendent is Joe Schmeizer. Approximate start date: July 10.




Laney Directional Drilling Co. was awarded a contract by ExxonMobil Pipeline Co. for the installation of 1,123 ft of 8-in. pipeline via directional drilling in Colorado County, Texas. Headquarters is on the jobsite. The superintendent is Jerry Cordova. Approximate start date: July 10.

Foltz Welding Ltd. (d/b/a Continental Pipeline Services) was awarded a contract by Panhandle Eastern Pipe Line Co. for the abandonment of approximately 2 miles of 12-in. pipeline in Texas County, Okla. Headquarters is unknown. The superintendent is Joe Pennington. Approximate start date: July 9.

BigInch Fabricators and Construction Inc. was awarded a contract by Panhandle Eastern/Trunkline Gas Co. for the take up and re-lay of approximately 600 ft of 24-in. pipeline in Parke County, Ind., and the relocation of 600 ft of 30- and 26-in. pipeline in Elkhart County, Ind. Headquarters are Goshen and Rockville, Ind. The superintendent is Jim Shepler. Approximate start date: July 8.

Foltz Welding Ltd. (d/b/a Continental Pipeline Services) was awarded a contract by Oneok for the installation of approximately 200 ft of 20-in. pipeline via directional drilling in Oklahoma County, Okla. Headquarters is unknown. The superintendent is Gary Kliebolker. Approximate start date: July 8.

Foltz Welding Ltd. (d/b/a Continental Pipeline Services) was awarded a contract by Koch for the relocation and installation of approximately 100 ft of 8-in. pipeline in Madison, Ill. Headquarters is unknown. The superintendent is William Grimes. Approximate start date: July 8.

Laney Directional Drilling Co. was awarded a contract by Plains All American Pipeline for the installation of approximately 2,576 ft of 12-in. pipeline via directional drilling in St. Mary Parish, La. Headquarters is on the jobsite. The superintendent is Oscar Myers. Approximate start date: July 8.

Pipeline Energy Group Inc. (d/b/a Carl Smith Pipeline) was awarded a contract by Mark West Liberty for the installation of approximately 8.2 miles of 20-in. pipeline in Guernsey and Harrison counties, Ohio. Headquarters is Cambridge, Ohio. The superintendent is Donald “Bub” Smith. Approximate start date: July 8.

Utility Services Authority LLC was awarded a contract by Associated Pipe Line Contractors Inc. for the installation of approximately 5,180 ft of 20-in. pipeline via horizontal directional drilling at three locations in Mahoning and Columbiana counties, Ohio. Headquarters are on the jobsites. The superintendent is Ervin Yoder. Approximate start date: July 8.

BigInch Fabricators and Construction Inc. was award-ed a contract by Panhandle Eastern for the installation of approximately 1,700 ft of 6-in. pipeline via directional drill-ing, the hydrostatic testing of approximately 10.1 miles of 6-in. pipeline, and the re-lay of 650 ft of 6-in. pipeline in Fulton, County, Ill. Headquarters is Canton, Ill. The super-intendent is Frank Ayers. Approximate start date: July 1.

Right-of-Way Clearing and Maintenance Inc. was awarded a contract by Precision Pipeline LLC for the clearing of approximately 8.99 miles of 6- to 16-in. pipeline rights of way in Sullivan County, Pa. Headquarters is unknown. The superintendent is James Merenda. Approximate start date: early July 2013 (announced July 1).

Snelson Companies Inc. was awarded a contract by Pacific Gas & Electric for the hydrostatic testing of approximately 6.5 miles of 12-in. pipeline in Kern County, Calif. Headquarters is unknown. The superintendent is Marv LaRue. Approximate start date: July 1.

Snelson Companies Inc. was awarded a contract by Pacific Gas & Electric for the installation of approximately 10 miles of 12-in. pipeline in Stanislaus County, Calif. Headquarters is unknown. The superintendent is Lou McMullen. Approximate start date: July 1.

U.S. Pipeline Inc. was awarded a contract by Enbridge for the installation of approximately 150 miles of 36-in. pipeline in Linn, Bourbon, Allen, Neosho, Wilson, Montgomery and Chautauqua counties, Kan., and Washington and Osage counties, Okla. Headquarters is Independence, Kan. The superintendent is Jim Jennings. Approximate start date: unknown (announced July 1).

U.S. Pipeline Inc. was awarded a contract by Enbridge for the installation of approximately 150 miles of 36-in. pipeline in Saline, Lafayette, Johnson, Cass and Bates counties, Mo.; Linn County, Kan.; and Osage, Pawnee, Payne and Lincoln counties, Okla. Headquarters are Warrensburg, Mo., and Sand Springs, Okla. The superintendent is Thad Hutchens. Approximate start date: unknown (announced July 1).


WANT To SEE yoUR PRoJECT HERE?

Send submissions to Managing Editor Brad Kramer at [email protected] with the subject heading “Project Roundup.”

Through the slop and across mucky terrain, the postman’s creed comes to mind. “Neither rain nor snow, nor sleet nor dark of night

shall stay these couriers from the swift completion of their appointed rounds.” The same should be said of crawler carri-ers on a pipeline right of way.

These track-driven multitaskers have been around for decades, but pipeline contractors are starting to find them invaluable tools on the jobsite, according to Mike Crimaldi,

president of Rig Source Inc. and Ter-ramac. Crawler carriers were the first choice to carry mats onto project sites to create more stable working environments for larger construction equipment. Their ability to access any terrain made them the ideal tool for such work, but that same quality is now compelling contractors to find other tasks for these machines.

Terramac is a newer manufacturer, having grown out of Rig Source Inc., which started in 2004 as a rental,

repair and support vendor for drill-ing contractors in the United States. The company specializes in installing drill rigs on used carrier platforms. A couple years ago, Crimaldi saw an op-portunity to dive into manufacturing crawler carriers for the U.S. market. The Terramac RT9 offers an easy-at-tach mounting system on the front and rear of the unit for a variety of configurations and applications.

Interchangeability between dif-ferent tools has become one of the


Carrying the LoadMultitasking Crawler Carriers serve the PiPeline industry

By Bradley Kramer


main drawing points for crawler car-riers, according to Doug Little, direc-tor of sales at Prinoth. While carriers don’t feature quick-attach couplers like a skid steer or hydraulic exca-vator, the machines can switch be-tween tool platforms in a matter of an hour or two.

Prinoth manufactures a wide range of tracked utility vehicles and equipment for the construc-tion market, including its North American-made Panther series of

crawler carriers that are specifically aimed at the oil and gas sector. Last year, the company celebrated its 50th anniversary.

Aside from carrying mats, crawler carriers are now being used on oil and gas construction projects on ap-plications such as welding, drilling, site investigation and material han-dling. The versatile machines range in price from $100,000 to $400,000, depending on specs, features and tool mounting choices.

low iMPaCt, high versatility

One of the major selling points of crawler carriers is the low ground pressure rating that these tracked units provide. This attribute allows the machines to cross roadways or environmentally sensitive areas with minimal to no damage, and they won’t get stuck.

“Crawler carriers range from very big to very small, but they’re built in

Crawler carriers can be outfitted with a variety of tools to assist pipeline construction. The machine’s low ground pressure allows them to perform heavy lifting with minimal environmental damage.

This webinar will focus on horizontal directional drilling (HDD), pipe bursting and cured-in-place pipe (CIPP) trenchless techniques specifically for the gas industry.

Horizontal Directional Drilling: A high-level review will be provided on state-of-the-art HDD applications and processes, equipment, material, tooling and bore tracking along with equipment design, planning and drilling fluids.

Pipe Bursting: Design, planning, construction, troubleshooting and mitigation best practices will be reviewed for gas industry applications.

Cured-in-Place Pipe: Applications, design, construction, testing and maintenance practices will be discussed as they relate to the gas industry.

The following industry experts from the NASTT membership will be presenting:

• Dr. David Bennett, Bennett Trenchless Engineers

• Collins Orton, TT Technologies Inc.

• George Ragula, Public Service Electric & Gas (PSE&G)

EducationalSeries2013

Cost: FREE Presented by Produced by

NASTT is pleased to host 3 webinars in 2013:

• Tuesday, June 25 HDD, Pipe Bursting and CIPP for the Gas Industry

•Wednesday, September 25 Sliplining

•Thursday, November 7 Sewer Laterals

North American Society for Trenchless Technology’s (NASTT) complimentary webinar series is modeled to bring you professional instruction from leading experts in the field of trenchless technology. The content of all NASTT training is peer-reviewed, consensus-based information and free of commercialism. Design to share the many benefits of trenchless technology, NASTT’s complimentary webinar series welcomes industry newcomers and seasoned veterans alike.

Go to www.trenchlessonline.com/index/webinars

TM

TM

HDD, Pipe Bursting and CIPP for the Gas Industry

such a way that their ground pressure rating stays about the same,” Little says. “An average man exerts about 11 psi, which is twice the amount of pressure exerted by one of these ma-chines carrying 40,000 lbs.”

Typical crawler carriers range be-tween 2 to 5 psi, depending on base operating weight and load capacity. The machines usually weigh about 10,000 to 30,000 lbs, with payloads from 12,000 to 46,000 lbs. Their low ground pressure and hefty pay-load allows them to attack a variety of tasks without sacrificing jobsite accessibility.

“The reason they’re so popular is that they can be used with different attachments for use on pipeline proj-ects,” Crimaldi says. “You can outfit them with welding machines, use them as personnel carriers, or add hydroseeding units or mulch blow-ers. On the right of way, there’s no

road, just dirt, so if it rains, access is terrible. A track carrier makes it suit-able for all ground conditions. “

Both Crimaldi and Little liken crawler carriers to trucks.

“Anything seen anywhere on the back of a truck can be put on the back of these,” Little says.

However, by having tracks instead of tires, Crimaldi says contractors don’t have to worry about accessibil-ity on a rainy day or wearing deep ruts into the landscape.

The three most popular configura-tions of crawler carriers used on oil and gas pipeline jobsites are with welding machines, dump boxes and flatbeds, according to Little. For weld-ing applications, crawler carriers can be mounted with welding machines, tents and a small crane to manipu-late the other equipment. Dump boxes are used to haul material, such as sand for pipe backfill. Flatbeds are

usually used to move mats around so that bigger equipment can get around the jobsite.

Crawler carriers are also popular in oil and gas exploration.

To improve interchangeability on crawler carriers, manufacturers like Terramac and Prinoth are developing mounting systems that reduce the time and difficulty of switching from one application to another.

“For instance, in mining explora-tion, you need a drill, but you also need support items for the drill, like rods, water for lube, a shack to store core samples and to keep out of bad weather,” Little says. “If you had a dedicated vehicle for each item, you’d have five vehicles on one site. What we’ve done is adapted a roll-off system, so that one vehicle brings in each tool on a platform.”

Different tool platforms or beds can also be attached with temporary


Crawler carriers used to be the ideal tool for hauling mats so that larger machinery could access a pipeline right of way. Now, the machines are tackling on more and more duties on the jobsite.

welding, a hook lift system or brack-ets and bolts.

“If you attach a welding machine to a bed, you can remove that bed in less than an hour and then attach an-other bed in another hour,” Crimaldi says. “Within a couple hours, one machine can be used for different ap-plications, which also makes them great for rental companies that have customers looking to use the ma-chines for multiple jobs. They can switch out the bed for whatever the customer needs.”

the effiCienCy arguMent While low ground pressure and

versatility are top reasons for why crawler carriers are gaining in popu-larity on oil and gas pipeline jobsites, those qualities add up to another benefit: efficiency.

“For the customers we’ve worked with so far, they’re all looking for the

same thing and that’s ease of work,” Little says. “When using bull dozers and other heavy equipment, once you get to a roadway, it becomes a pain because you have to put down mats. You have to have extra pieces of equipment to put down the mats and block traffic. With rubber tracked car-riers, you can just go across the road. There’s no damage done and no delay. You don’t have to stop traffic as long. Low ground pressure also means less environmental impact compared to a wheel loader or bull dozers.”

The draw of efficiency has led to crawler carriers taking on more and more tasks.

“When I first started working with customers in the oil and gas indus-try, everyone knew tracked carriers were primarily used for moving mats around,” Little says. “The big thing now is that they’re used for many more things. Contractors are seeing

with tracked carriers, they eliminate some of the hassle and time it takes to use extra machinery that tracked carriers are now used for. The innova-tion in the oil and gas industry is not the vehicle itself, but how it’s used.”

Crawler carriers can help reduce construction costs by eliminating the need for additional machinery and reducing environmental impact and restoration costs.

“They save time, effort and mon-ey,” Little adds.

the right ChoiCeWhile the merits of crawler carriers

are many, there aren’t too many crite-ria to consider when looking to rent or purchase a unit.

“Depending what it’s used for, cus-tomers usually go by carrier capac-ity,” Crimaldi says. “The Terramac RT9 is sort of in between two sizes to add a little more drive capability. The


Dump boxes are one of the more popular configuration of crawler carriers for the oil and gas sector. These beds can be switched out with other options to enhance versatility.

heaviest carrying capacity possible on our machine is a non-permitted load. That way they can go from one jobsite to another, and they don’t need a special permit.”

The main thing to look for in a crawler carrier, Crimaldi says, is the power of the unit.

“If you’re on a jobsite where you’ll be climbing hills, you need to make sure you have enough drive torque,” he says. “The other measuring tool is how the machine is rated on carrying capacity and ground pressure.”

Little agrees that carrying capac-ity is the primary deciding factor be-tween machines and that the weight of the mounted tools or bed is a big consideration.

“Customers want the carrier to get the tools they work with to where they need to go,” he says. “The main determining factors are payload of-fered vs. the weight of the tools they’re using. A welding machine for instance, the total welding pack-age with canopy is about 6,000 lbs, so you need to look for a machine with a capacity of 6,000 to 8,000 lbs to carry that. You don’t want to be underpowered and risk getting stuck, which leads to costly downtime.”

If you size the equipment properly, Little says, you virtually eliminate most problems that could come along.

a growing Market

Although crawler carriers have been around for more than 20 years, Crimaldi says the machines have been growing in popularity over the last 10 years. As contractors are find-ing more uses for the rubber-tracked utility vehicles, a shortage of avail-ability arose.

“I jumped into the market be-cause I saw a demand,” says Crimal-di, whose Rig Source Inc. supplied used machines for the construction market. In recent years, he saw that the lead time for receiving a new carrier became longer and longer and availability of used machines was little to none.

“Demand was always there,” he says. “We were looking for more ma-chines all over the world in whatever condition. I decided to take destiny into my own hands and try to fill the gap. Demand never seemed to stop, but production lead time for avail-ability was six to eight months. If you waited that long, you’d be in a differ-ent season.”

Terramac has continued to grow, as it recently secured its first distribu-tor in the U.K. The company already has dealers across the United States and Canada. The oil and gas pipeline market makes up a majority of the company’s business. Crimaldi sees the “new gold rush” in the Bakken shale as a major driver for the crawler carrier business moving forward.

Little agrees, adding that oil and gas pipelines look “very strong for the next four to seven years.”

“There are huge projects in the planning stages and awaiting per-mitting or awaiting President

Obama to give the OK,” Little says. “There’s a tremendous amount of work to go around. The raw materi-als have to get somewhere, and all pipelines contribute to that in some way or other.”

As oil and gas resources need to be transported to market, construction materials need to be hauled across those pipeline jobsites. Crawler carri-ers can carry the load.

Bradley Kramer is managing editor of North American Oil & Gas Pipe-lines. Contact him at [email protected].



s shale gas development continues to boom in the United States, prospects to the north seem to be stall-

ing amid low natural gas prices in Canada. However, several pipeline and storage facilities projects are on the books to meet demand for more transportation capacity throughout the provinces.

The Canadian National Energy Board (NEB) released its “Short Term Natural Gas Deliverability 2013-2015” in May. This market assess-ment indicated that Canadian natu-ral gas producers are undertaking minimal natural gas drilling activity as current prices do not cover the full costs of developing most natural gas prospects.

The NEB examined trends for natu-ral gas deliverability in Canada (the ability to produce natural gas from

new and existing wells) and found that three key supply and demand drivers were influencing future Cana-dian natural gas deliverability:1. Minimal drilling activity because

prices do not cover the costs of developing most natural gas pros-pects.

2. Growth in natural gas as a byprod-uct from developing oil and natu-ral gas liquids (NGL) rich prospects.

3. Producers are not earning suffi-cient returns to attract additional equity investment with current prices of around $3/MMBtu in western Canada.Furthermore, the report indicates

that the addition of pipeline capac-ity to deliver shale gas from the Mar-cellus shale region is bringing forth additional deliverability into an al-ready fully supplied North American

market, displacing Canadian natural gas exports in the Northeast U.S. and some domestic sales in central Can-ada. Further displacement of Cana-dian natural gas could occur due to the developing Utica shale in Ohio.

Due to lengthy project develop-ment timelines, the NEB determined that significant liquefied natural gas (LNG) exports from North America are unlikely through the 2015 time horizon of its analysis. LNG exports are therefore not expected to influ-ence gas prices and gas drilling over the study period.

Despite these dower prospects, pipe-line companies are still busy develop-ing a number of projects, which have already begun construction or are awaiting regulatory approval. What follows is an overview of many of the natural gas pipeline projects currently under way or in the permitting process.

Canadian Gas Projects Slowed by Pricing NEB Expects Holding Pattern for Producers in 2013 By Bradley Kramer

NATURAL GAS PIPELINES REPORT p

ip

e

l i n e r ep

or

t

A


Coastal GasLink Pipeline ProjectLocation: British ColumbiaStakeholder(s): TransCanada Corp., Shell Canada Ltd., LNG CanadaOverview: Coastal GasLink Pipeline Ltd. proposes to build an approxi-mately 650-km pipeline from the Dawson Creek area to the British Co-lumbia coastline. The pipeline will transport natural gas to the proposed LNG Canada facility near Kitimat. The Project study corridor was established based on a preliminary assessment of terrain, environment, social aspects and constructability, and through engagement of landowners, Aborigi-nal communities and the public. The proposed route for regulatory review and approval will be determined by considering Aboriginal, landowner and stakeholder input, the environ-ment, archaeological and cultural values, land use compatibility, safety, constructability and economics. The project, which was announced in June 2012, would involve construc-tion with 48-in. diameter pipe, in addition to the construction and op-eration of up to three meter stations and one compressor station. The ini-

tial capacity would be approximately 1.7 billion cubic feet per day (bcf/d). Environmental field studies began in January, in anticipation of submit-ting an Environmental Assessment Application in early 2014. Construc-tion, pending all required regulatory and project approvals, is expected to begin in 2015.

Mackenzie Gas ProjectLocation: Northwest TerritoriesStakeholder(s): TransCanada, Imperial Oil Resources, ConocoPhillips Canada, Shell Canada Ltd., ExxonMobil Canada and the Aboriginal Pipeline Group (APG). Overview: The Mackenzie Gas Project (MGP) is a proposed 1,196-km natu-ral gas pipeline and gas gathering sys-tem, liquids extraction, liquids pipe-line and related field developments along the Mackenzie River valley of Canada’s Northwest Territories. The NEB approved a Certificate of Public Convenience and Necessity for the project in March 2011. The approval contained 264 conditions, including the requirement to file an updated cost estimate and report on the deci-sion to construct by the end of 2013

and that construction must com-mence by December 2015. The proj-ect proponents continue to monitor ways to move the project forward, but so far natural gas market condi-tions do not signal a commercially viable opportunity. The stakeholders have reduced spending on the proj-ect to a minimum, but are seeking a solution to allow project activities to be restarted in the future. If de-velopment of the project ultimately goes ahead, it would result in a pipe-line being constructed from Inuvik, Northwest Territories, to the north-ern border of Alberta, where it would connect to TransCanada’s system.

NEXUS Gas Transmission ProjectLocation: OntarioStakeholder(s): Enbridge, Spectra Energy and DTE EnergyOverview: The proposed NEXUS Gas Transmission Project (NGT) is a joint venture among Enbridge, Spectra Energy and DTE Energy and is being developed to support the growing demand for natural gas in the upper U.S. Midwest and eastern Canadian regions. With a decline in

western Canadian natural gas sup-plies to these regions, the proposed NGT system is designed to transport at least 1 bcf/d of growing supplies of Ohio Utica shale gas to the high-demand markets in Ohio, Michigan and Ontario, Canada. The proposed path for NGT will consist of a newly constructed, greenfield pipeline that will extend approximately 250 miles from receipt points in eastern Ohio to interconnects with the existing pipe-line grid in southeastern Michigan. As proposed, the path will utilize both existing and expansion capac-ity on the interstate pipeline system owned by Vector Pipeline LP to ac-cess the Dawn Hub in Ontario and the Enbridge Tecumseh storage facil-ity. The NGT system is targeted to be in service as early as November 2016, depending on final market demand, commitments and necessary regula-tory approvals. The project must ob-tain regulatory authorizations from the U.S. Federal Energy Regulatory Commission (FERC) and the NEB, as well as other Canadian agencies.

Niagara Link Gas Storage Location: OntarioStakeholder(s): Enbridge Inc.Overview: Enbridge is conducting an open season to assess the feasi-bility of developing incremental gas storage capacity and services at its Enbridge Gas Distribution’s (EGD) Tecumseh storage facility located near the Dawn Hub in Ontario. The proposed project would also include the development of incremental gas transportation capacity between Te-cumseh and Dawn, as well as offering incremental, seamless, single trans-porter service between Corunna and Dawn via an extension to the existing Niagara Gas Link Pipeline. Enbridge has a range of storage and transporta-tion development options which can be put into place in a timely basis to take advantage of market opportu-nities such as U.S. shale gas and gas fired generation. Enbridge will deter-mine the overall need for incremen-tal capacity and associated facilities required, based upon market demand for services. The proposed in-service date for the project is Nov. 1.

North Montney Extension ProjectLocation: British ColumbiaStakeholder(s): NOVA Gas Transmission Ltd. (NGTL), a subsidiary of TransCanada Corp.

Overview: The proposed $1.5 bil-lion North Montney Mainline will be a large-diameter extension from the existing Groundbirch Main-line section of the NGTL system in northeast British Columbia. The project will consist of two sections, Aitken Creek and Kahta, totaling ap-proximately 305 km in length and will include associated metering facilities, valve sites and possible compression facilities. The project will also include an interconnec-tion with TransCanada’s proposed Prince Rupert Gas Transmission (PRGT) project to provide natural gas supply to the proposed Pacific NorthWest LNG export facility near Prince Rupert, British Columbia. Pending necessary regulatory ap-proval, NGTL expects the Aitken Creek section to be operational in the second quarter of 2016, the Kahta section in the second quarter of 2017 and the export delivery fa-cilities in 2019.

Northwest System Expansion ProjectsLocation: British Columbia, AlbertaStakeholder(s): NGTL (TransCanada)Overview: NGTL is proposing to construct and operate a number of expansions and an extension to its pipeline system in northeastern British Columbia and northwestern Alberta. The need for and timing of these projects are influenced by the pace and location of producer activity, commercial support and TransCanada’s pipeline system ca-pabilities. The company applied to the NEB for all of these projects in several different applications be-tween the first and third quarters of 2011. The NEB approved the 33-km Chinchaga Loop in May. The 48-in. diameter pipeline will parallel the existing Chinchaga Lateral sys-tem and is scheduled to be in ser-vice by April 2014. The expansion projects also include the Hidden Lake North Compressor Station, the Moody Creek Compressor Station, both in service in 2012; the Horn River Mainline Loop (Kyklo Creek Section), in service in April 2013; Northwest Mainline Loop (Timber-wolf Section), in service in April 2013; Tanghe Creek Lateral Loop (Cranberry Section), in service in April 2013; and Tanghe Creek Lat-eral Loop (Sloat Creek Section), in service in April 2013.

Parkway ProjectLocation: OntarioStakeholder(s): TransCanadaOverview: TransCanada recently re-ceived NEB approval to construct the Eastern Mainline Expansion Project, which includes the 12.9-km Parkway Pipeline. The Parkway project will consist of a 42-in. diameter pipe-line that parallels, in two separate sections, a portion of the existing TransCanada Mainline in the cities of Brampton and Vaughan, Ontario. The project will also include mi-nor system modifications at various TransCanada facility sites through-out southern Ontario. The Parkway Pipeline will increase capacity on TransCanada’s natural gas transmis-sion system providing the markets in the Greater Toronto Area (GTA) and Central Southern Ontario with ad-ditional natural gas supply. This in-creased capacity will provide for the commercial commitments of supply-ing Marcellus shale gas to these mar-kets. The pipeline will be constructed along TransCanada’s existing right of way to reduce environmental effects and minimizing disruption to nearby residents and landowners. In January, contractors completed horizontal di-rectional drilling to cross the Credit River, with tie-in completed later in the spring. Cleanup and reclamation of the jobsite is ongoing to restore the land to its previous condition.

Prince Rupert Gas Transmission ProjectLocation: British ColumbiaStakeholder(s): Progress Energy Canada Ltd., TransCanadaOverview: In January 2013, Trans-Canada was selected by Progress En-ergy to design, build, own and oper-ate an approximately 750-km natural gas pipeline in northern British Co-lumbia. If approved, the Prince Ru-pert Gas Transmission (PRGT) project will deliver natural gas from a point near the District of Hudson’s Hope to the proposed Pacific Northwest LNG facility on Lelu Island, within the District of Port Edward. A concep-tual corridor (an initial draft of the pipeline route) has been created for discussion and planning purposes. Input from Aboriginal groups and stakeholders, such as landowners, local communities and government, will help shape the final route. The final route will also reflect the terrain, environment, constructability and economics of the project. Environ-


mental and engineering studies be-gan in June, with an environmental assessment application expected to be submitted in early 2014. Construc-tion is scheduled to begin in 2015, with the pipeline in service in 2018.

Spectra Energy/BG Group Natural Gas Transportation SystemLocation: British ColumbiaStakeholder(s): Spectra Energy, BG GroupOverview: The proposed project from northeastern British Columbia to Prince Rupert, British Columbia, would include approximately 850 km of pipeline with a capacity of up to 4.2 bcf/d. The project will provide the required natural gas transporta-tion capacity to meet the demands of a proposed LNG terminal on British Columbia’s coastline, in keeping with the provincial government’s Jobs Plan and its goal of establishing LNG facilities by 2020. The project also will connect with the Spectra Energy system at Station 2 (southwest of Fort St. John), a growing natural gas hub that collects supply from multiple areas of the province and other sup-ply basins in Western Canada. The project is expected to be in service by 2019.

T-North 2011 ProjectLocation: British ColumbiaStakeholder(s): British ColumbiaOverview: Spectra’s T-North 2011 project comprises two 36-in. diam-eter pipeline segments near Fort St. John, British Columbia, with one being 24 km and the other 30 km long. The pipelines provide a ca-pacity of approximately 170 mil-lion cubic feet per day (MMcf/d). The 24-km pipeline construction involved looping on Spectra’s Fort Nelson Mainline between Compres-sor Station N4 and Compressor Sta-tion N5. The construction of the 30-km pipeline, dubbed the “Stew-art Lake Pipeline,” extended from Spectra Energy’s existing Fort St. John Mainline southeast to NGTL’s Groundbirch Receipt Meter Station. The project also involved the in-stallation of a new compressor unit at Compressor Station N4 and the construction of a new compressor station at the southern end of the Stewart Lake Pipeline, called the “Sunset Creek Compressor Station.”

Spectra Energy’s pipeline system is well positioned for future growth

based on customer need and timing. A second binding pipeline open sea-son in 2010 resulted in a further 550 MMcf/d committed under long term demand-based arrangements sup-porting a further expansion of the T-North system, which is currently underway.

This is not a comprehensive list of the pipeline projects for the upcom-ing construction season. For updates regarding ongoing projects, refer to

the Project Roundup on page 14 and published each issue.

North American Oil & Gas Pipelines will provide a report on U.S. gas pipe-line projects in the November issue. The Canadian and U.S. oil pipeline re-ports were published in the February and May issues, respectively.

Bradley Kramer is managing editor of North American Oil & Gas Pipelines. Email [email protected] to contact him.


In May, Standard & Poor’s manag-ing director David Wood said that the United States’ anticipated en-

ergy self-sufficiency by the end of this decade would directly result from the oil and gas produced from shale plays. As a leading manufacturer of heavy equipment used every day in this booming industry, Hyundai wanted to get a closer look at the outlook

for shale gas, the specialized equip-ment needs that shale development requires and the maintenance and service challenges that happen out in the field. The company turned to two of its dealers that specialize in equip-ping customers working in the shale gas industry — Four Seasons Equip-ment of North Dakota and Highway Equipment Co. in Pittsburgh.

While 2012 saw a shale slowdown on the East Coast, all you have to do is check in with the equipment rental industry to see that 2013 is anything but slow.

“The equipment rental business in the Marcellus and Utica gas shale plays in western Pennsylvania and Ohio is incredible,” says Al Springer, sales and marketing director with


Equipment Needs and Challenges in Shale ProductionBy Shane Sirmons

Supplying the Shale

www.napipelines.com

Highway Equipment Co. “In 2012, there was a slowdown in the gas drill-ing and related construction work until the midstream sector could catch up with the supply of natural gas and liquid natural gas. Nineteen new natural gas and natural gas liq-uids processing plants have been or are currently being built in Pennsyl-vania and Ohio.”

Brad Brousseau, vice president of operations for Four Seasons Equip-ment, serves the oil and gas industry in the Bakken region and says new leases are being opened up every day, with a backlog of wells waiting for completion.

“We are seeing strong demand for equipment,” Brousseau adds. “Our customers in the shale production in-dustry are coming to us for Hyundai excavators in the 20- to 30-ton cat-egory, such as the R210LC-9 and the R250LC-9, and 4-cubic yard wheel loaders, like the Hyundai HL760-9A.”

In the Marcellus and Utica shale plays, Springer says that the three most popular models and sizes of Hyundai excavators used by the con-tractors are the Hyundai R380LC-9 (84,220 lbs), R290LC-9 (64,600 lbs) and R210LC-9 (48,460 lbs).

“When they need a wheel loader they select a Hyundai HL740TM-9 with bucket, standard forks and pipe and pole forks,” he says.

The attachments required for gas drilling and related work can be just as important as the machines them-

selves. Four Seasons is equipping most of its excavators with a hydrau-lic quick coupler that allows the op-erator to quickly change buckets and other attachments such as compac-tion plates, compaction wheels, clea-nout buckets and hammers. Wheel loaders are being equipped with hy-draulic quick couplers, 96-in. pipe forks, buckets and extenda-booms.

“The increased focus on safety in this region has seen the demand in-crease for multiple, specialized prod-ucts,” Brousseau says.

Specialization and customization are also important in the Marcellus and Utica shale plays.

“Due to the rugged terrain that these excavators are working in throughout western Pennsylvania and Ohio, excavators require single grouser bar track pads,” Springer says. His dealership also equips Hyundai excavators and wheel loaders with several special attachments, invest-ing in keeping them in stock to equip his large rental fleet so his customers don’t have to wait for an attachment to come in.


Getting the Best Service

Shale industry contractors should notice a more competitive market for the heavy equipment sales and rental market. The Bakken area, for instance, is seeing existing heavy equipment dealers start serving this industry as well as new rental and sales compa-nies entering the market. However, contractors may want to do their re-search and choose a heavy equipment dealer that understands this industry.

“The equipment that is required by the shale gas contractors is unique and not often used by other construction contractors,” Springer says. ”Therefore, the typical construction equipment rental dealer or national equipment rental chain company chooses not to be committed to this market. I recom-mend that the contractors working in the shale gas industry search for the equipment that they need and will do their job. Don’t settle for just any piece of equipment that might work. It’s ok to pay a little higher rental rate to get what you know will work.”

Another challenge that shale gas contractors and equipment dealers

face is maintaining and servicing their heavy equipment in the field. To start with, it can be difficult to locate the piece of equipment that needs work.

“Just finding the project where the equipment is being used is a challenge,” says Springer. “These projects are in the middle of nowhere. Hyundai’s Hi-Mate System with GPS helps us tremendously. We not only know where the machine is working and how to get there, but we also know when it is time for all the service intervals.”

The Hi-Mate Remote Management System allows operators and dealer ser-vice personnel to access a machine’s vi-tal service and diagnostic information from anywhere with Internet access. Hi-Mate users can remotely monitor daily reports outlining a machine’s lo-cation, working hours, fuel consump-tion and any periodical maintenance needed, drastically reducing downtime and saving the owner time and money.

Brousseau recommends that wheel loader and excavator operators make general maintenance a priority.

“That includes twice daily greas-ing and cleaning,” he says. “When a

loader is on location it is subject to a multitude of chemicals and abrasives that can shorten the life of pins and bushings. I recommend and remind all our customers of the importance of preventative maintenance. A tub of grease and a grease gun is a lot less expensive than a complete set of new pins and bushings.”

Fortunately for operators of Hyun-dai’s 9 and 9A-series machines, bush-ings are designed for extended lube intervals of 250 hours — and poly-mer shims to resist wear and reduce noise. You also get extended-life hy-draulic filters (1,000 hours), long-life hydraulic oil (5,000 hours) and more efficient cooling systems and integrated preheating systems. These help extend service intervals thus re-ducing operating costs and machine down time.

Highway Equipment Co. serves the Marcellus and Utica shale gas indus-try in Pennsylvania, Ohio, West Vir-ginia and New York. In business since 1933, the company has established itself as one of the region’s leading rentals, sales and service providers.

Four Seasons Equipment of North


edu.benjaminmedia.com | 330-467-7588

Topics Covered Include:* HDD Applications

and Process* Equipment and Materials* Planning and Jobsite

Safety* Risk Reduction, Mitigation

and TroubleshootingPrice:

$39.99*

Horizontal Directional Drilling - Good Practices Guidelines (2004 Edition)

Publisher: HDD Consortium Softbound/98 Pages

*Shipping and handling not included. Selling price Subject to change without notice.

Experts in HDD wrote this book to provide contractors, engineers and owners with a set of guidelines that will assist and allow your personnel to produce successful HDD installations.

Dakota is owned by Four Seasons Equip-ment Inc. (FSEI), es-tablished in 2001. FSEI also has locations in Texas and Louisiana. The company is a full-service heavy con-struction equipment dealer providing sales and rentals.

Hyundai Construc-tion Equipment Amer-icas Inc. offers a variety of earthmoving and materials-handling equipment for the pipeline industry, in-cluding hydraulic ex-cavators, wheel load-ers, skid steer loaders and electric and die-sel forklifts. They also manufacture internal combustion cushion and internal combustion pneumatic forklifts.

Shane Sirmons is marketing manager for Hyundai Construction Equipment Americas.


The equipment that shale gas contractors typically use is unique and

not often used by other construction contractors. Dealers suggest

contractors shop around to ensure they get the equipment they need for the job.


Hydraulic fracturing is contro-versial, and that controversy certainly is not completely un-warranted. To fully understand

the many issues with fracking and how to improve the process, reduce its environmental impact and quell the fears of those who are against it or lack a comprehensive understanding of it, one must first realize that public opinion is rather easily manipulated by fear. That fear is based on environ-mental concerns, both known and the possibility of further problems yet to be discovered. It is perpetuated by organizations that want to see all fracking completely banned.

The primary target of derision is how drillers use water. Ironically, this is directly in line with the in-dustry itself, which responded that water management is the No. 1 issue in need of regulation, according to a recent survey conducted by Ecologix Environmental Systems among oil and gas industry professionals.

Since water issues top the list of concerns by both environmentalists and the industry, the key to bridging the gap between the two is agreeing on appropriate water treatment. For-tunately, there is a simple solution that satisfies both sides: wastewater management. Fracking opponents

will be glad to know that drillers who treat flowback water can greatly reduce their need to withdraw fresh water while at the same time elimi-nate disposal of chemically infused water. Drillers will be pleased to hear that this solution is not only cost-effective, but it actually improves the productivity of wells.

Water goes through a process, or lifecycle, when used for fracking.

AcquisitionFracking a well requires water. A lot

of water. While the amount needed varies, an average is roughly between 3 million and 5 million gallons. Data

Responsible Fracking

Bridging Environmental Concerns by Energy ProductionBy Eli Gruber


on how many hydraulic fracturing wells are in operation is not specif-ic, but a safe assumption is that the number is in the tens of thousands at any given time. So hundreds of thou-sands of wells exist, and each one needs an average of 3 million to 5 million gallons of water — and that’s per frac. Some wells can be fracked multiple times.

It’s easy to see how high water us-age for fracking skyrockets. Where is all this water coming from? The short answer is that it is purchased on the open market. Drillers purchase the right to withdraw water from land-owners whose property sits above an aquifer, since water rights are tied to land ownership. This is in contrast to mineral rights, which are usually pur-chased and traded independently of the land above. Drillers then extract the water from underground aqui-fers, the same places that irrigation and drinking water come from.

TransportSince aquifers frequently are not

located near drilling sites, water must be transported. The most common method of water transport is via tank-er truck. A frac that requires only 3 million gallons of water would need 350 tanks of water, each of which must be hauled by trucks, one at a time, as they burn fossil fuels and cause wear and tear on roadways. Often, local communities also dislike the disruption this causes to traffic flow and noise levels.

Once the water has been delivered and used, it must be discarded in a disposal well, requiring additional transport to get there. Therefore, double the number of trips on the water’s journey: Our well has now re-quired 700 tanker truck trips to oper-ate. Like proximity to aquifers, many drilling sites are not located near disposal wells and the water must be hauled great distances, often across state lines. A remote hydraulic frac-turing operation could require more than 50,000 cumulative miles of wa-ter transport.

FrackingWhen fresh water arrives on site,

it is infused with a slurry of chemi-cals that serve a variety of purposes, including lubrication and dissolv-ing debris in the fissures created by the fracking process. A proppant, or coarse material usually made of sand,

is also added to the mixture in or-der to penetrate into the frac fissures and keep them open and producing. The mixture of water, chemicals and proppant is colloquially referred to as “frac fluid.” This frac fluid is com-monly 90 percent water. Sand or an-other proppant makes up 9.5 percent of the mixture with various chemicals contributing the final 0.5 percent, ac-cording to the American Petroleum Institute (API).

The frac fluid is piped into the well, and over the next several days most of it flows back to the surface. What comes back is called flowback water, and it includes the original frac fluid, but it also picks up many naturally occurring chemicals from under-ground. Additionally, it mixes with oil freed from shale by the fractur-ing process and highly saline natural brine water from the depths where fracking occurs.

WastewaterBecause of its level of contamina-

tion before any treatment happens, flowback water is considered waste. Since it takes several days for most flowback water to reach the surface, drillers usually store it on site until the flow has slowed. The most com-mon storage technique is to dig a temporary pond, line it with heavy-duty materials and let the flowback water pour into it. Large storage tanks can also be used to temporarily hold the flowback water, and some states are now requiring this and banning open-air pits.

Once all the flowback water has reached the surface, drillers load it into tanker trucks and haul it to dis-posal wells. These are usually dor-mant, empty wells left over from conventional drilling. Once flowback water has filled a disposal well, the top is capped off and the water is permanently sealed thousands of feet below ground where it stays away from the environment, never to see the light of day again. Not only does this create a net deficit in the natural water balance, disposal wells are also controversial themselves and some studies have linked them to increased seismic activity.

Because of the complex steps water has to go through to be used in frack-ing — withdrawal, transportation, chemical infusion and disposal — the public has valid reason for concern. While technological solutions that

permit less water to be used in the process are in their developmental infancy, operators still have an ob-ligation to minimize impact on wa-ter resources and should be held ac-countable for usage.

Water TreatmentThe best solution for water used

in fracking is for operators to treat it themselves instead of disposing it. There are many competing systems tailored for this exact purpose avail-able, including the Integrated Treat-ment System (ITS) available from Ecologix Environmental Systems. Each system works differently, but the goals of all of them are the same — to prevent flowback water from be-ing permanently discarded, or rather to permit flowback water to be reused in the fracking process.

Wastewater management addresses environmental concerns on three main fronts:

Withdrawal — Frac wastewater treatment systems are not engineered to create potable water; that process is simply too expensive. Instead, the water is treated for the needs of the fracking industry. This enables treat-ed water to be reused over and over in new fracs, greatly reducing the need to withdraw fresh water from local sources.

Transportation — Treatment sys-tems built for fracking are mobile and can be located on individual sites or strategically placed to service multi-ple nearby wells simultaneously. This greatly reduces the distance the water must travel, and in many instances temporary pipelines can be installed to eliminate the need for truck haul-ing entirely.

Storage — The longer untreated flowback water is stored, the greater the opportunity it has to cause envi-ronmental damage. This water can be treated almost immediately after it flows back and stored. Open-air pits or storage tanks filled with treated water are much less problematic to the environment than when they contain untreated flowback water.

The reduction of environmental im-pacts that treating wastewater enables is one side of the coin; the benefit it provides to drillers is the other. This benefit comes in the form of increased


productivity of the well. Each shale formation has different compositions throughout that can vary, even with-in the same well at different depths. Understanding and mapping these variations can be calculated into the water treatment process so that as water is treated, it is also conditioned to interact properly with the natural chemistry of the well. Properly condi-tioned water ensures that the fissures created by fracking remain open and allow maximum flow of trapped oil and gas. This increased productivity almost always more than offsets the expense of treatment programs.

Educating the Public and Industry

The big question is, if treating frac water is a solution that reduces im-pact on the environment and helps drillers get more output at a lower cost, why isn’t it standard operating procedure? The answer is a combina-tion of inertia and education. Much like a locomotive at full speed re-

quires more than a mile to stop, drill-ers have been fracking the same way for years and the method has inertia. Fresh water is relatively cheap, the tanker truck industry is established, and there are thousands of disposal wells ready to accept wastewater. It’s a tried and true method.

The other problem is education. There are many drillers who simply do not know that a better way exists. Some who do know may be skeptical of implementing new methodologies unknown to them. The education component also extends to the pub-lic. On one side of public opinion you have, “Drill, baby, drill.” And on the other you have, “Ban fracking now.” Like most politically charged issues, the public’s opinion lies somewhere in between these extremes. If more people understood that there existed a way to balance energy needs with protecting natural resources, there surely would be increased public buy-in of fracking.

It’s clear that fracking as an energy production method will remain a

part of our energy future. So instead of sitting at opposite ends of the table, environmentalists and energy drillers should come together to pro-mote the idea of responsible frack-ing. This can be accomplished by educating the general public, activists and the industry on the ways water treatment companies are mediating the lynchpin issues in the industry: protecting water resources and ensur-ing proper treatment to protect the environment. Lawmakers also can be encouraged to draft enlightened leg-islation that sets standards for water withdrawal, disposal and treatment that require oil and gas extraction to be carried out responsibly and re-spectfully. The technology to do so exists, and it’s just a matter of getting the right people to care.

Eli Gruber is president and CEO of Ecologix Environmental Systems, an Alpharetta, Ga.-based wastewater treatment company specializing in in-dustrial wastewater treatment. Contact him at [email protected].

By recycling water used in hydraulic fracturing, drilling companies can reduce the environmental impact of shale oil and gas development. Ecologix provides a mobile treatment solution, the Integrated Treatment System.

►

For the thousands of lakeside dwellers and tourists who live and play at Missouri’s famed Lake of the Ozarks,

the arrival of economical, clean-burning natural gas has been a long time coming. Hilly terrain, steep cliffs, extremely hard rock lurking just below the surface and lack of re-cords documenting the location of existing underground utilities — all have been impediments to making the excursion.

Now, after years of trepidation about the feasibility of successfully completing a relatively short 49-mile trek from nearby Lincoln, Mo., to the Lake of the Ozarks — located about three hours southwest of St. Louis — officials with Summit Natu-ral Gas of Missouri Inc. have decided the time to initiate the pipeline jour-ney has arrived. Summit Natural Gas of Missouri currently serves more than 11,000 customers throughout the state; and as evident by this lat-est venture through the hilly, rock-laden terrain enveloping the Lake of the Ozarks, the energy leader is affirming its commitment to bring natural gas services to areas current-ly not served.

Four years in the making — plan-ning, surveying, securing right-of-way acquisitions, mapping the route, hiring contractors and marketing the service to potential new custom-ers — the Summit project involves installing more than 2 million ft of 6-in. HDPE natural gas pipe through some of the densest rock found any-where in the United States. When completed, this extensive pipeline network will provide natural gas to the towns of Gravois Mills, Laurie, Sunrise Beach, Camdenton, Osage Beach and Lake Ozark, Mo.

More than 30 percent of the pipe-line — approximately 600,000 ft — is being installed by horizontal directional drilling (HDD) technol-ogy. The largest and most costly components of the Summit project — three trenchless bores beneath the lake at sites alongside the three major bridges in the area: the Com-munity Bridge, Hurricane Deck and Niangua — were also the most vis-ible and challenging. Lone Star Di-rectional Drilling, based in Clarks-


Monumental Pipeline Journey

Three Trenchless Bores Deliver Energy to Missouri’s Lake of the OzarksBy Randy Happel

ville, Texas, was selected by general contractor J.F. Construction Servic-es, based in DeWitt, Mo., to com-plete the bores. John Dagenhart, founding partner of Lone Star Di-rectional Drilling and a veteran of more than 20 years with HDD work, explains the rationale for selecting the Vermeer D1000x900 Navigator horizontal directional drill for the challenging lake-crossing bores.

“We’re using the D1000x900 drill for many reasons,” Dagenhart says. “For a maxi drill, the D1000x900 drill is a relatively easy system to operate … and it’s powerful. The drill is also very durable and reliable, which is important given the complexity and the length of the three lake crossings. We knew the D1000x900 drill had the capabilities to effectively power through the rock. But because of the intricate complexity of the lengthy bores, accuracy and durability are also critical.”

Highly Visible, Highly Sensitive

Dagenhart recalls the first visit he made to the lake with Jim Frock, founder of J.F. Construction Services,

to survey the new Summit project installation route. Among the many objectives of the trip was to identify launch sites with enough area to ac-commodate the drill and various sup-port equipment necessary for com-pleting the three lake crossings as specified in the drill plan.

“Finding launch sites with enough flat area in close proximity to where we’d be drilling was a challenge,” Dagenhart says. “There are few areas of flat space desired for launch sites because the steep terrain is preva-lent right up to the lake’s edge. All three bores were also situated near or alongside bridges, where the depth of the water averages from 90 ft to more than 100 ft. Since we were required to maintain a 40-ft clearance, the bores needed to reach a depth of 150 ft very quickly; a challenging feat given the proximity of the launch sites to the lake’s edge.”

The first bore, completed alongside the Niangua Bridge, consisted of a continuous 3,500-ft shot that took just less than a month to complete. The second was a 3,600-ft shot locat-ed near the Community Bridge. Just completed, the third and final lake crossing was a 6,000-ft bore near Hur-

ricane Deck where, coincidentally, a new bridge was also being built.

“Construction of the new bridge, along with concerns levied by the bridge construction contractor in-volving the demolition of the old bridge, prompted an alteration to the tolerance,” Dagenhart says. “The specified tolerance on that bore was increased to 100 ft. As a result, the bore near the Hurricane Deck Bridge required reaching a depth of 278 ft quickly.”

A 9 7/8-in. chisel bit with tungsten carbide inserts was chosen for all three bores. “We’ve found that once we encounter rock in excess of 6,000 psi, depending on the pipe we’re in-stalling, bits with tungsten carbide inserts will last longer,” Dagenhart says. “This was important on a bore of this length, beneath the lake, that we not have to pull back and change a worn bit before completing the shot. Experience told us this was the type of bit we needed to use.”

In addition to the limited space for establishing a launch site and strict tolerances required in the drill plan, the hard rock — much of which is fractured in gravel, cobble and some limestone — presented ad-


Lone Star Directional Drilling was called in to execute three bores to install a natural gas pipeline to serve the scenic

Lake of the Ozarks in Missouri. The three bores ranged from 3,500 to 6,000 ft in environmentally sensitive area.

ditional challenges for the Lone Star drill team. Given the tough condi-tions, Dagenhart has been pleased with the average daily production rates by the D1000x900 drill of ap-proximately 300 ft per day. “If we can average 10 pipe joints a day, we’re very happy,” he says.

Back reams weren’t necessary on the first bore, although, on the Com-munity Bridge crossing, where the drill plan specified 8-in. diamater steel pipe compared to the 6-in. in-stalled on the first shot, the bore path was back-reamed once with an 18-in. hole opener.

Given the environmental sensitiv-ity associated with this pristine lake setting, additional precautions have been implemented including the ad-dition of secondary containments under all motors, screen mesh of specified sizes around the pump to alleviate entry by fish, and special ar-eas for accessing water for use in the drilling process.

“We received permits to extract water from the lake, but are limited to specific access points,” Dagenhart says. “It’s all in an effort to mini-mize risk of something unfortunate happening that could threaten the environmental integrity of the lake;

all precautions that come into play when drilling around a lake.”

An elaborate reclaiming system — with 1,000-gpm capacity — is recapturing more than 75 percent of drilling fluid presented into the bore path; a straight bentonite and water mixture Dagenhart has found to be most effective in rock-laden conditions.

“We’re reclaiming and reusing all of the drilling fluid that comes back out of the hole,” he says. “More and more water is required to build up the volume of drilling fluid as the bore progresses. Bores of these lengths re-quire a tremendous amount of fluid, so the more we can recoup and re-cycle, the more efficient we are com-pleting the shots.”

After overcoming several obsta-cles, and responding to unexpected challenges and unanticipated de-lays, the Lone Star crew has success-fully completed the three highly monitored lake crossings without incident. With the recent comple-tion of the third and final Hurri-cane Deck Bridge bore, Lone Star crews have begun the process of tying the pipe together and testing the gas line to prepare residents for the much-anticipated arrival of this

valuable and economical energy re-source to their homes and business-es. And after more than two decades in the underground pipeline busi-ness, Dagenhart admits he learns something new — or something he’s learned previously is reaffirmed — on every job.

“Be flexible,” he says. “Despite the aggravations and things I worry about every morning when making my way to a jobsite, it is nice know-ing I don’t have to worry about our Vermeer drill rig. There are so many variables on every job; things that are out of our control. So, it’s good to know that I can always rely on our drills.

“In the rare event that something does go haywire, the folks with Ver-meer Texas-Louisiana are always right there to take care of it. Not only is the equipment built tough, but the service they provide is second to none. It’s one of those very impor-tant things that I sometimes take for granted because I simply don’t have to worry about it.”

Randy Happel is a features writer for Two Rivers Marketing, based in Des Moines, Iowa. This article was written on behalf of Vermeer, of Pella, Iowa.


More than 30 percent of the pipeline — approximately 600,000 ft — is being installed by

horizontal directional drilling technology.

PiP

el

ine

Pr

od

uc

t e

xP

o

Flow-Cal Enterprise Software SuiteFlow-Cal Inc. is a leading provider of measurement software solutions that automate the validation and reporting of EFM devices. Flow-Cal’s products begin at the field level, where its PROVEit, PYCit, CALCit and TESTit applications are designed to schedule and record the calibration and testing of field equipment. The flexibility and power of the applications have allowed them to be used by both the liquid and gas divisions within an organization.

The suite of field products augments the functionality of Flow-Cal’s flagship product, FLOWCAL Enterprise. Enterprise is used throughout the industry to validate, recalculate, store and report gas and liquid measurement data.

Flow-Cal’s PROVEit application is used to prove, track and manage meter performance data. Using either volumetric or mass calculations, PROVEit conforms to the API guidelines. The PYCit software application is designed to calculate and manage a company’s density meter proving information, employing the latest API Chapter 14.6 algorithms. Flow-Cal’s TESTit software provides a measurement technician with an advanced progression of automation tools for meeting their calibration and sampling requirements. The CALCit software uses the latest

industry standard calculations for gas volume, plate size and liquid correction factors, assisting in the validation of other systems.

For more information, visit www.flow-cal.com.

General Monitors TS4000H Toxic Gas Detector The TS4000H Intelligent Toxic Gas Detector from General Monitors has been approved by the International Electrotechnical Commission (IEC) and found to be in compliance with international safety standards for explosive environments. The TS4000H offers protection against a wide range of hazardous industrial gases and is able to safeguard against oxygen deficiency.

With its advanced design, the TS4000H Toxic Gas Detector offers many valuable features including event logging, a clearly visible LED and an indicator for remaining sensor life. The detector is easy to install and can self-calibrate. Process engineers who need to protect people, equipment and the environment will find the TS4000H well suited for a broad range of industries, including petrochemical installations, oil and gas production facilities, water and wastewater treatment sites and power plants.

The TS4000H monitors a variety of toxic gases like ammonia, carbon monoxide, chlorine, chlorine dioxide, hydrogen, hydrogen

chloride, hydrogen sulfide, nitric oxide, nitrogen dioxide, oxygen deficiency, ozone and sulfur dioxide. The system displays gas concentrations up to 500 ppm, fault codes for troubleshooting, prompts when calibration is needed, and provides complete status to the control room.

For more information, visit www.generalmonitors.com/Gas-Detectors.

McCrometer V-Cone Flow MeterMcCrometer’s space-saving V-Cone Flow Meter is an advanced differential pressure instrument, which is ideal for use with liquid, steam or gas media in rugged conditions where accuracy, low maintenance and cost are important. With its differential pressure built-in flow conditioning design, the V-Cone Flow Meter is especially useful in tight-fit and retrofit installations in which the long runs of straight pipe required by Orifice Plates, Venturi Tubes and other technologies are either impractical or unavailable.

The V-Cone Flow Meter is designed for today’s most challenging oil/gas production applications. This flow meter is a better solution because it combines exceptional performance, low maintenance and long life for superior value.

exPoPiPeline Product


PiP

el

ine

Pr

od

uc

t e

xP

o

With its unique differential pressure cone design, the versatile V-Cone Flow Meter provides superior flow measurement accuracy and repeatability regardless of space and weight constraints. McCrometer’s field-proven flow measurement solutions have met the demanding production environment of the oil and gas industry for more than three decades.

Third-party testing to the American Petroleum Institute’s API 22.2 Testing Protocol for Differential Pressure Flow Devices confirms the V-Cone’s highly accurate flow measurement with minimal pipe runs. The V-Cone also is available with international certifications such as Measurement Canada, INMETRO and many others.

For more information, visit www.mccrometer.com.

Nextteq Gastec Detector Tube SystemNextteq’s complete line of Gastec pumps and detector tubes precisely measure gases and vapors in more than 600 applications, making it an invaluable tool for gas detection and measurement as well as detecting leaks and fugitive emissions.

Gastec’s pump is easy-to-use, lightweight and rugged. Its one-stroke piston action provides reliable operation with no partial samples. Nextteq’s Thermal Ring provides on-the-spot measurement of ambient temperature for tests that require temperature correction.

Measurement is fast, convenient and accurate. The direct-read length of stain tubes offer distinct lines of demarcation for easier viewing. Gastec Detector Tubes are intrinsically safe and always ready to use anytime, anywhere.

With Gastec, end-users can rapidly measure many substances that

can’t be measured with electronic gas detection devices, and no other detector tube manufacturer can measure more substances than Gastec.

To review chemicals and measuring ranges of the Gastec Detector Tube System download a copy of the Gastec 18th Edition Tube Guide from the company’s website in the Featured Products section on the home page.

For more information, visit www.nextteq.com.

SITRANS FUS-LDS Leak Detection SystemThe Siemens FUS-LDS Leak Detection System offers a complete

software and hardware solution for liquid pipelines. The FUS-LDS uses clamp-on ultrasonic flow meters mounted directly onto the pipeline. SIMATIC WinCC leak detection software monitors all flow meters and pipeline segments, serving as a quick and reliable way for the pipeline operator to detect and localize leaks.

The FUS-LDS does not require continuous operator attention, because the alarm thresholds are pre-set and alert the operator when attention is needed. The system also has the ability to detect very small leaks by allowing the operator to utilize “visual trending.” A fully optimized system eliminates the occurrence of false alarms.

The Siemens FUS-LDS Leak Detection System meets API 1130 “Computational Pipeline Monitoring for Liquid Pipelines” and PHMSA 195.444 CPM Leak Detection requirements for safety, helping to protect the environment and limit contamination issues.

This system lives up to the requirements of pipeline

companies and regulatory agencies while ultimately satisfying one major goal: providing users and the community with peace of mind.

For more information, visit www.usa.siemens.com/flow.

T.D. Williamson STOPPLE Train Plugging SystemT.D. Williamson’s STOPPLE Train plugging system is a double-block and bleed patented design that makes it possible to insert two plugging heads through a single fitting. The void between the two plugging heads can be bled down to provide a “zero energy” zone. Both plugging heads are rated to 1,480 psi at 180 degrees F, or reduced pressures at temperatures up to 350 F.

As a result of using the STOPPLE Train system, TDW customers reap the benefits of enhanced safety and reduced costs normally associated with fitting, welding, inspection services, scaffolding and crane rental, excavation services and fewer “hot work” permits.

The method offers a significant improvement over traditional double-block and bleed methods, which require twice the number of line penetrations. Costs associated with the purchase and welding of fittings are reduced by 50 percent because just one set is required.

The STOPPLE Train system has been used successfully for customers seeking to carry out routine maintenance and emergency repair work on pressurized piping systems located subsea, in remote onshore environments and in refineries and processing plants.

For more information, visit www.tdwilliamson.com.


Free Subscription!Fax to 888.585.0180Please start/renew my free* subscription to North American Oil & Gas Pipelines ■ Yes ■ No

What is your company’s primary activity? (check only one)

A Excavation ContractorsB Pipeline ConstructionC Pipeline MaintenanceD EngineeringE Consulting (Legal, Financial)F Government/RegulatoryG Transmission PipelinesH Distribution PipelinesI Exploration/ProductionJ Equipment Mfg/SupplierK Other ___________________

Which types of equipment or services do you recommend for use in the oil & gas pipeline industry? (check all that apply)

A Cathodic TechnologyB Cleaning PigsC Coatings/LiningsD Corrosion MonitoringE Environmental AwarenessF Flow Control SoftwareG GIS/GPS systemsH Inline InspectionI Leak Detection/PreventionJ Offshore Pipe LayingK Pipe MaterialsL Pipeline CommunicationsM Pipeline Design EngineeringN Pipeline MachineryO Pipeline MaintenanceP Pipeline RehabilitationQ Pipeline SafetyR Pipeline SecurityS Project Financing & InsuringT ROW ManagementU SCADA/Automation SoftwareV Trenching MaterialsW Trenchless TechnologyX WeldingY Other _________________________

What is your primary job title/function at your company? (check only one)

A Owner /CEO/PresidentB Executive Mgr/VP/COO/CFOC Financial ManagerD SuperintendentE ManagerF General ManagerG DirectorH Engineer /ConsultantI Supervisor /ForemanJ AttorneyK Other ___________________

PLEASE PRINT CLEARLY

Name ___________________________________________________________________

Title _____________________________________________________________________

Company ________________________________________________________________

Address _________________________________________________________________

_________________________________________________________________

City _____________________________________________________________________

State/Prov _______________________________________________________________

Zip/Postal Code _______________________________Country ___________________

Phone ___________________________________________________________________

Fax _____________________________________________________________________

Email** __________________________________________________________________

Signature ________________________________ Date___________________________

Yes, I want the bi-weekly E-newsletter.**www.napipelines.com *The subscription is free in the USA, Canada & Mexico

**Please include your email to receive the bi-weekly E-newsletter NAOGP0813

Don’t Miss An Issue!

Scan this code with your smart phone and

subscribe online!

Quarterly Regional Oil and Gas Pipeline ReportsPipeline Integrity and Maintenance Shale Oil and Gas ChallengesCanadian Oil Sands DevelopmentSoftware and New Technology ToolsProduct Showcases, Project Updates, News, Trends and More in Every Issue!

SubScribe Today for 12 more iSSueS of

WAtch for theSe AnD other feAtureS In future ISSueS:

The go-to resource for choosing large equipment

for the oil and gas industry.


Business Cards

ClASSIFIEDATTENTION CLEARING CONTRACTORSFor rent, with operator. Union and non-union jobs. 2006 Timbco 445 EXl with 24” 360 deg hotsaw.

10 years of experience.

Call for more details Willis Collier | 317-563-2404


North American Oil & Gas Pipelines Calendar

Advertiser .....................................Website .......................................................Page

BMI Resource Center ...................edu.benjaminmedia.com .................................32

Canusa ..........................................www.canusa.com ...............................................7

Enviro-Span ..................................www.enviro-span.com ......................................45

E-Z Line Pipe Support Co. ............www.ezline.com ................................................15

FAE USA Inc..................................www.faeusa.com ..............................................13

Farwest Corrosion Control Company .......................www.farwestcorrosion.com ..............................11

Fecon Inc. .....................................www.fecon.com ................................................29

Foremost Industries ......................www.foremost.ca ................................................9

Girard Industries ...........................www.GirardIndustries.com ...............................27

HDD Seminar ................................www.trenchlessonline.com...............................41

Horizontal Technology Inc. ...........www.horizontaltech.com ..................................23

Hyundai Construction Equipment .....www.hcamericas.com ...................................................5

IHI/Compact Excavator Sales ......www.IHICES.com .............................................31

Advertiser .....................................Website .......................................................Page

iploca .............................................www.iploca.com ...............................................45

John Deere ...................................www.JohnDeere.com/excavator ........................3

Laney Directional Drilling ..............www.laneydrilling.com ......................................12

Mattracks ......................................www.mattracks.com .........................................33

McLaughlin ...................................www.mightymole.com ......................................17

Mesa .............................................www.mesaproducts.com .................................45

NASTT Webinar ............................www.trenchlessonline.com/index/webinars .....21

NASTT’s No-Dig Show .................www.nodigshow.com .......................................19

North American Oil & Gas Pipelines Buyer’s Guide ......www.napipelines.com ......................................30

Polyguard Products ......................www.PolyguardProducts.com ..........................48

TD Williamson ...............................www.tdwilliamson.com .......................................2

Trenchless Roadshow ..................www.trenchlessroadshow.com ........................47

Welded Construction L.P...............www.welded.com .............................................25

Advertisers Index

The evenTs PiPelineConferences, Meetings & Trade Shows

2013AUGUST 20-21Western Regional Gas ConferenceTempe Mission Palms Hotel and Conference Center Tempe, Ariz. Web: www.westernregionalgas.org

21-22GeoGatheringGIS for Gathering and Production LinesColorado Springs, Colo.Web: www.geogathering.com

26-28LNG Export DevelopmentHoustonWeb: www.lngexportusa.com

26-28SURF TechnologiesHoustonWeb: www.SURFTechnologies.com

26-28Tulsa Pipeline ExpoTulsa, Okla.Web: www.tulsapipelineexpo.com

28-29Eagle Ford Markets & Takeaway Capacity JW Marriott HoustonWeb: www.eagle-ford-markets-2013.com

SEPTEMbER9-114th Annual bakken Infrastructure Finance & Development Week 2013Bismarck, N.D.Web: www.infocastinc.com/events/bakken13

10-11Oil Sands Trade Show and ConferenceSuncor Community Leisure CentreFort McMurray, AlbertaWeb: www.oilsandstradeshow.com

17-19Canada LNG Export ForumCalgary, CanadaWeb: www.canadalngexport.com

23-27IPLOCA ConventionOmni ShorehamWashington, D.C.Web: www.iploca.com

OCTObER 1-3ICUEEKentucky Exposition CenterLouisville, Ky. Web: www.icuee.com

7-9Oil & Gas AutomationHoustonWeb: www.oilgasautomation.com

NOvEMbER3-5AEM Annual ConferenceHilton Bonnet Creek & Waldorf AstoriaOrlando, Fla.Web: www.aem.org

2014JANUARY23-24Pipe Tech Americas SummitThe Woodlands Waterway Marriott Hotel and Convention CenterThe Woodlands, TexasWeb: www.pipetechamericas.com

FEbRUARY4-9DCA Annual ConventionRitz CarltonCancun, MexicoWeb: www.dcaweb.org

18-21PLCA Annual ConventionHyatt Regency Coconut PointBonita Springs, Fla.Web: www.plca.org

MARCh4-8ConExpo – Con/AggLas Vegas Convention CenterLas VegasWeb: www.conexpoconagg.com

MAY11-15PLCAC Annual ConventionVancouverWeb: www.pipeline.ca

12-14Pipeline Technology ConferenceHannover, GermanyWeb: www.pipeline-conference.com

SEPTEMbER30-Oct. 2 International Pipeline Conference & ExpoTELUS Convention CenterCalgary, AlbertaWeb: www.internationalpipelineexposition.com

Holiday Inn Boxborough 242 Adams Place Boxborough, MA 01719

NOVEMBER

12-13 BOSTON, MA

MAIN EVENT SPONSOR :

www.trenchlessroadshows.com

Live Demos

Trenchless Education

(C.E.U.)

Industry Exhibits

Keynote, Bernie Krzys CEO/Publisher

of Benjamin Media Inc. 2012 NASTT Hall of Fame

"The premier vehicle for learning all aspects of trenchless new construction and rehabilitation techniques."

brought to you by:

COFFEE SPONSOR :LANYARD SPONSOR:

north american oil & gas pipelines · has announced plans to build two new pipelines over the...

Documents