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4 North American Oil & Gas Pipelines | FEBRUARY 2012 napipelines.com

ON THE COVER: Drilling for natural gas in shale formations is the latest craze in energy development, but it’s also highly controversial. Industry experts explain the benefits and challenges of this booming resource.

18 Cracking the Shale Natural gas remains a driving force in energy supply and industry growth.

By Bradley Kramer

FEATURES

24 Obama Denies Keystone Permit TransCanada to reapply for approval of its pipeline project. By staff reports

26 All Wrapped Up The evolution of composite repair in the pipeline industry.

By Amanda Hawkins and Roger Walker

28 Coat of Protection Pipelines and the importance of external corrosion.

By Richard Norsworthy and John Strong

32 Big Rentals Know your needs before renting a heavy excavator for your next project.

By Doug Zoerb

36 Oil Pipelines in the North Reporting the latest developments in Canadian oil pipelines.

By Bradley Kramer

DEPARTMENTS8 News

15 Market Watch

16 Project Roundup

42 Product Showcase

45 Events Calendar

COLUMNS6 Editor’s Message

MARKETPLACE45 Index of Advertisers

46 Business Cards

February 2012Volume 5 Issue 2Published by Benjamin Media, Inc.

North American Oil & Gas Pipelines is published twelve times per year. Copyright 2012, Benjamin Media Inc., 1770 Main St., Peninsula OH 44264. USA All rights reserved. No part of this publication may be reproduced or transmitted by any means without written permission 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 Peninsula office. POSTMASTER: send Changes of Address to North American Oil & Gas Pipelines, P.O. Box 190, Peninsula OH 44264 USA.

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Mixed Signals in WashingtonAll of the above or none at all? If one thing is clear about

President Barack Obama’s hopes for “American-made energy,” it’s that he’s sending mixed messages to the energy industry.

On the one hand, he calls for “an all-out, all-of-the-above strategy that develops every available source of American energy — a strategy that’s cleaner, cheaper and full of new jobs.” On the other hand, he denies TransCanada’s Keystone XL pipeline, proposes new taxes on the oil and gas industry and scales back the amount of land available for shale gas and oil sands development.

The president’s actions don’t seem to measure up to his words. In the 2012 State of the Union address in January, Obama touted an eight-year high in American oil production.

“Over the last three years, we’ve opened millions of new acres for oil and gas exploration, and tonight, I’m directing my Administration to open more than 75 percent of our potential offshore oil and gas resources,” Obama said during the speech. In addition to the record oil production in the United States, he added that the country relied less on foreign oil in 2011 than in any of the past 16 years.

And yet, he said no to a project that would deliver Canadian oil to the Gulf Coast and create thousands of construction jobs. The Keystone pipeline has been under review by the government for the past three years, yet the Obama administration couldn’t determine that the project served the national interest of the United States within a 60-day deadline that was imposed by the Temporary Payroll Tax Cut Con-tinuation Act, passed Dec. 23, 2011.

TransCanada is in the process of reapplying for a permit to build its Keystone XL pipeline, which we detail further on Page 24 of this issue.

While U.S. oil reserves account for only 2 percent of the world’s oil reserves, Obama said “oil isn’t enough,” and the country needs to further develop its abun-dant natural gas supply.

“We have a supply of natural gas that can last America nearly 100 years, and my administration will take every possible action to safely develop this energy,” Obama said. “Experts believe this will support more than 600,000 jobs by the end of the decade. And I’m requiring all companies that drill for gas on public lands to disclose the chemicals they use. America will develop this resource without putting the health and safety of our citizens at risk.”

The natural gas industry has already taken such measures on its own by imple-menting a website, www.fracfocus.org, to track natural gas wells and for companies to disclose the chemicals used in drilling fluids (Page 18).

“The development of natural gas will create jobs and power trucks and factories that are cleaner and cheaper, proving that we don’t have to choose between our environment and our economy,” Obama said, but then he announces this month that he’s proposing to scale back the amount of land available for shale drilling and to impose higher taxes on the oil and gas industry as a whole.

“The president’s 2013 budget plan returns to the well of bad ideas and backtracks on his State of the Union commitment,” said Jack Gerard, American Petroleum Insti-tute president and CEO. “Instead of advancing constructive pro-development policies, his budget plan calls for increased taxes on America’s oil and natural gas industry.”

Gerard argues that increasing taxes on the industry would push oil and natural gas investment overseas and diminish job creation and economic activity in the United States.

Obama might say he wants more domestic energy production, but his actions are sending the wrong signals.

Brad KramerAssociate [email protected]


Publisher Bernard P. Krzys

Associate Publisher Robert D. Krzys

Editor James W. Rush

Associate Editor Bradley Kramer

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Andrew Farr Keith Gribbins Pam Kleineke Kelly Pickerel

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Regional Sales Managers Ryan Sneltzer

Dan Sisko

Audience Development Manager Alexis R. White

Web & Interactive Manager Mark Gorman

Conference Event Coordinator Vicki Losh

Editorial Advisory Board

Cortez Perotte Pipeline Product Engineer/Industry Representative,

Caterpillar Inc.

Todd Porter Vice President of Business Development,

New Century Software Inc.

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 Vice President, Michels Corp.

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Editor’s Message


North America News

PipeLine Machinery International (PLM-Cat) executive vice president and general manager Tony Fernandez wel-comed local pipeline industry representatives, media and community to the grand opening of the company’s new head office facility in Cypress, Texas, on Feb. 9. Cypress is located in the northwest Houston area.

“We are all very proud of this new facility,” Fernandez said. “Creating this efficient and comfortable base for our international operations was a long time coming and a welcome change for our team. We no longer need to rent local yard and service facility space and our head office operations are housed with our equipment which brings us all closer to our everyday business.”

The PLM-Cat World Headquarters is centered on more than 18 acres of land just off State Highway 290 in north-west Houston. The 8,800-sq ft service facility includes a state-of-the-art equipment wash bay designed to con-serve, clarify and reuse water. Paved and gravelled storage areas can accommodate approximately 150 large units.

PLM-Cat chief financial officer Ted Hill worked closely with the designer and contractor on the office build. “It has been a very interesting project for me and certainly gratifying to see the final product,” he said. “The de-signers, Powers Brown Architects, and the contractor, Burton Con-struction, have built us a unique and forward-looking space that we can enjoy for many years to come.”

The 16,000-sq ft office facility includes 4,000 sq ft of open space for future development plus some room on the property for build-ing expansion. Office space is available for 50 with 30 people currently working out of this office. Meeting and training fa-cilities onsite will accommodate more than 50 people.

A New Tool for PipelinersDuring the grand opening of its new headquarters,

PLM-Cat also announced its latest machine for pipeline installation. Fernandez presented to the crowd the com-pany’s newest pipelayer offering — the 72H.

“The 72H resulted from listening to the needs of our customers for a mid-range pipelayer and working with Caterpillar to find a solution,” Fernandez said. “What we came up with is a purpose-built pipelayer that combines the proven capabilities of the Cat D6T

base tractor with the Vanguard engineering expertise in pipelayer design.”

This 90,000-lb (40 823 kg) lift capacity machine bridges the gap between the lifting capacity of the PL61 (40,000 lbs/18 145 kg) and the heavy lifting PL83 (160,000 lbs/72 575 kg) and PL87 (214,000 lbs/97 079 kg). The 72H base tractor adaptations and pipelayer design once again feature the Vanguard Equipment engineering expertise (designers of the Cat 572R and 571M).

“We are pleased to offer this Tier 4 Interim- [and] EU Stage IIIB-class machine, which meets the most exacting emissions requirements in the world,” Fernandez said. The 72H requires ultra-low-sulphur diesel fuel readily available throughout North America and selected Europe-an countries. Future models in this weight class will also be available with earlier version engines for operation in countries without access to the required fuel grade.

PLM-Cat was established in 2005 and is the first Caterpillar dealership to focus on a particular industry on

a global basis. The company provides purpose-built and traditional construction equipment to the mainline pipe-line construction industry on projects around the world. PLM-Cat works closely with pipeline owners, contractors and local Caterpillar dealers to provide solutions tailored to the unique product and service needs of this industry.

PLM-Cat’s worldwide activities are currently supported through the corporate offices in Cypress, Texas; Edmon-ton, Alberta; The Hague, Netherlands; Beijing, China; Melbourne, Australia; and Singapore.

PLM Opens the Doors at New World HeadquartersNew Pipelayer Unveiled at Grand Opening Event in Cypress, Texas

PLM-Cat opened its new world headquarters in Cyprus, Texas, a suburb northwest of Houston.

napipelines.com FEBRUARY 2012 | North American Oil & Gas Pipelines 9

Survey: Majority of U.S. Voters Favor More Oil, Natural Gas Development

They want more energy, according to the results of a poll released Jan. 18, which found that 70 percent of U.S. voters favor increased access to U.S. oil and natural gas resources. A similar number of those surveyed also believe more oil and natural gas development would provide major benefits to the United States, including more jobs.

“Voters know developing more of America’s homegrown energy makes sense for our economy and our energy secu-rity,” said American Petroleum Institute president and CEO Jack Gerard. “Our economy will demand large amounts of oil and natural gas for at least several more decades even as the role of alternative energy increases. Common sense says we should have Americans producing that oil and gas here at home as much as possible.”

According to the recent API telephone poll, conducted by Harris Interactive, among 1,005 registered voters found that large majorities believe that more U.S. oil and natural gas development could lead to more American jobs (87 percent), help the U.S. economy and reduce consumer energy costs (83 percent), increase the nation’s energy security (82 per-cent) and deliver more revenue to the government (72 per-cent). More than two-thirds (70 percent) believe that some in Washington are intentionally delaying domestic oil and natural gas development, potentially hurting the economy and leading to higher energy costs for consumers.

The United States is the world’s largest producer of natural gas and third largest producer of oil. It has very substantial reserves of both in part because of technological progress in offshore development and in the development of shale oil and natural gas onshore.

The study was conducted Dec. 13-15, 2011, via telephone by Harris Interactive on behalf of the API, among 1,005 reg-istered voters across the United States, with a sampling error of plus or minus 3 percent.

CRC-Evans Aligns With Technip NorwayCRC-Evans Pipeline International Inc. has announced a

new strategic agreement between its offshore division and Technip Norway, a major offshore engineering contractor in the development of subsea fields on the Norwegian Conti-nental Shelf. According to the agreement, CRC-Evans Off-shore will provide all onsite welding services, including full supply of welding equipment and personnel to the Statoil Hyme and Vigdis mainline welding projects.

The agreement, which was signed in November and will be valid until 2014, extends the already strong 15-year relation-ship between Technip Norway and CRC-Evans. This contract furthers the scope of services provided by CRC-Evans in its longstanding collaboration with Technip Norway on the sup-ply of welding equipment, technicians and consumables for the Statoil Hyme and Vigdis projects. CRC-Evans will also be responsible for the management of the welding firing line for the projects, charged with achieving targeted productivity.

CRC-Evans Offshore projects director Scott Black believes the strategic agreement reinforces and cultivates the com-pany’s outstanding relations with Technip Norway.

“An excellent business relationship has been further strengthened through this updated frame agreement,” Black said. “We are excited to keep meeting the expanding needs of our friends at Technip.”

CRC-Evans will bring its newest equipment onsite — including the P625, P260 and CMT welding systems, pipe facing machines and internal clamps, which will include

the latest purge and laser systems. Due to this cutting edge technology and dedicated personnel, CRC-Evans has proposed a significant increase in production rates and site efficiency for the projects.

Double joint production began in November 2011 and mainline fabrication will commence in January 2012.

Chesapeake Energy Listed Among Fortune’s “100 Best”

For the fifth consecutive year Fortune Magazine named Chesapeake Energy Corp. to its list of “100 Best Companies to Work For.”

Moving up 14 spots from 2011, Chesapeake ranked No. 18 — the highest listed Oklahoma-based employer and the top ranked natural gas and oil producer. Fortune specifical-

ly noted Chesapeake’s high-paying career op-portunities and employ-ee perks and benefits as reasons for Chesa-peake’s strong showing in the annual list. The full list and related stories appear in the Feb. 6 issue of Fortune and is now available at www.Fortune.com/Best-Companies.

“While we celebrate any recognition of Chesapeake’s dynamic corporate culture, we

are most proud of the people who work for this company,” said Aubrey McClendon, Chesapeake CEO. “Our more than 12,500 employees are what make Chesapeake a great place to work. Through teamwork and a commitment to quality and safety, the Chesapeake team is fueling a brighter energy future for our country.”

Last year Chesapeake ranked No. 32 on Fortune’s list. Chesapeake’s climb in rank recognizes the company’s con-tinued efforts to offer the best in career growth, benefits and work environment.

In 2011, Chesapeake added new benefits for its employ-ees, including a state-of the-art, 63,000-sq ft child devel-opment facility in Oklahoma City, two full-time chaplains available to all employees and a comprehensive pregnancy wellness program for expectant mothers in all of the com-pany’s operating areas.

These benefits are in addition to a $1,500 cash incentive for employees to practice healthy lifestyles, four hours of company time for volunteer work with nonprofit organi-zations and a full company match of 401(k) contributions up to 15 percent of an employee’s salary, including perfor-mance bonuses. The company emphasizes career growth, and employees receive performance reviews, with opportu-nity for raises and bonuses, twice per year.

Oklahoma City employees also enjoy a 72,000-sq ft fitness center, a health center serving employees and their families, four on-campus restaurants and a sustainable employee garden stretching across an entire block.

“It is Chesapeake’s goal to be the most competitive em-ployer in both our industry and the country,” said Martha Burger, Chesapeake senior vice president of human and cor-porate resources. “The benefits we offer, in addition to our outstanding career opportunities, allow us to recruit and retain top talent. Chesapeake’s employees are the driving force behind the success of our company. We are commit-ted to caring for each other as colleagues and caring for the communities where we do business.”

Undermining U.S. Shale Investment the Wrong Approach to Energy Security

The U.S. Bureau of Land Management wants to cut down the amount of land available for energy development, but industry advocates say the move discourages investment in domestic resources. American Petroleum Institute presi-dent and CEO Jack Gerard called on the administration to reverse its course from the BLM recommendation on the grounds that it would limit access to developing energy resources in Colorado, Utah and Wyoming.

“Within a week of encouraging an ‘all of the above’ energy strategy, the administration has put on hold de-velopment of one of the nation’s most energy-rich areas,” Gerard said. “There will be no opportunity to invest for years. The administration is sending negative signals to industry and capital markets at exactly the wrong time.”

In 2008, the BLM proposed two million acres of federal land for oil shale and tar sands research and development, but the latest announcement would mean the govern-ment is cutting off more than 75 percent of those lands for research and development.

“Consistent and stable regulations are needed to promote the commercial development of oil shale, an important and strategic national resource,” Gerard said. “Reliable gov-ernance from the BLM in the management of this resource is essential to attract the significant investment capital needed to both advance needed technologies and begin development.”

Caballo Energy Acquires Eagle Chief MidstreamCaballo Energy LLC has expanded its natural gas foot-

print with the Jan. 18 announcement that it has acquired Eagle Chief Midstream LLC, which owns a gathering and processing system in northwestern Oklahoma.

The Eagle Chief assets are strategically located at the intersection of the liquids-rich Mississippi Lime and Cana Woodford Shale plays. Eagle Chief is connected to more


Chesapeake’s swank campus in Oklahoma City is just one of the reasons Fortune listed the company among its “100 Best Companies

to Work For.”


plays. The acquired acreage is characterized by high working interest and operatorship; approximately half is held by production.

“This is an important growth step for Apache — a unique bolt-on opportunity that more than doubles Apache’s acreage in a highly liquids-rich fairway in the Anadarko Basin,” said G. Steven Farris, chairman and CEO. “Apache has been active in the Basin for more than 50 years; the experience we have gained drilling 500 wells in the Granite Wash play — including 79 horizontals drilled since 2009 — gives us an in-depth under-standing of the geology and the operating environment and will enable us to hit the ground running.

“Multiple, stacked horizontal targets provide decades of potential drilling locations,” Farris added. “Because 80 percent of revenue comes from liquid hydrocarbons production, this transaction provides compelling economics at current commodity prices.”

than 370 wells and serves 25 producers.The Eagle Chief system includes more

than 600 miles of natural gas gathering pipelines, compression and processing assets located in Alfalfa, Blaine, Gar-field, Major and Woods counties. In early 2013, the company will install a new cryogenic plant, bringing total natural gas processing capacity to approximately 100 million cubic feet per day (MMcf/d).

Tulsa-based Caballo Energy is a mid-stream services company formed to ac-quire, develop and manage natural gas gathering, compression, treating, pro-cessing and marketing assets. The com-pany delivers processed gas to ONEOK Gas Transportation and Panhandle East-ern Pipe Line. Natural gas liquids are de-livered to ONEOK NGL Pipeline. The Ea-gle Chief system also includes salt water disposal and crude oil gathering systems.

Caballo Energy is backed by private eq-uity commitments from EnCap Flatrock Midstream of San Antonio.

“The Mississippi Lime and Cana Woodford Shale are two of the most ex-citing plays in the country,” said Dennis Jaggi, one of EnCap Flatrock Midstream’s three managing partners and a member of Caballo Energy’s board of managers. “We’re seeing a surge in drilling activity in northwestern Oklahoma in the Mis-sissippi Lime formation. This is a great acquisition in an underserved region with very strong demand for gathering, compression and processing services. Acquisition of Eagle Chief will enable Caballo Energy to grow as demand accel-erates. We look forward to working with producers to improve their economics by providing effective service and mul-tiple options for moving gas and crude to market.”

Apache to Acquire Cordillera Energy Partners for $2.85 Billion

Apache Corp. has expanded its foot-print in Oklahoma and Texas. The com-pany announced on Jan. 23 that it has agreed to acquire Cordillera Energy Part-ners III LLC, a privately held company with substantial operations that include approximately 254,000 net acres in the prolific Granite Wash, Tonkawa, Cleve-land and Marmaton plays in western Oklahoma and the Texas Panhandle, all for the sum of $2.85 billion.

In addition to estimated proved re-serves of 71.5 million barrels of oil equiv-alent (boe) and current net production of 18,000 boe per day, Cordillera has assembled a leading acreage position with significant resource potential in-cluding 14,000 potential drilling loca-tions in liquids-rich Anadarko Basin

The acquisition is expected to be accretive to Apache’s earnings and cash flow beginning in 2012. The develop-ment drilling program is self-funding beginning in 2013.

The sellers, including EnCap Investments, other in-stitutional investors and Cordillera management will receive approximately $600 million in Apache com-mon stock subject to customary lock-up provisions. The balance of the consideration will be paid in cash to be funded with debt. The effective date of the transaction is Sept. 1, 2011, with closing anticipated in the second quarter, subject to regulatory approval and customary closing conditions.

“This transaction presents a tremendous opportunity for Apache to combine the Cordillera assets with its legacy western Anadarko Basin position, creating a platform for a multi-decade development program in some of the most economic, oil- and liquids-rich gas targets in the onshore United States,” said George H. Solich, Cordillera’s president and CEO. “The combination is an excellent outcome for the Cordillera shareholders. We are taking a meaningful amount of the consideration in Apache shares, reflecting our confidence that the quality of the asset base will contin-ue to yield economic growth in production and cash flow for years to come.”

Cordillera will continue to acquire acreage in the area on Apache’s behalf through closing.

A wash, including the Granite Wash, consists of a series of thick, multi-layer, liquids-rich sandstones and conglomerates. While it is considered “tight” by conven-tional standards, the Granite Wash possesses reservoir properties superior to typical shale resource plays, and responds well to horizontal drilling with multi-stage frac-turing completions. A typical producing column in the acreage fairway is more than a mile thick with up to five liquids-rich Granite Wash targets and five additional oil-bearing tight sandstone targets. Approximately 50 percent of the hydrocarbon stream is liquid — condensate and natural gas liquids. Additional deep gas horizons include the Skinner, Atoka and Morrow. According to Oklahoma regulatory agencies, more than 60 separate formations currently produce oil and gas in the fairway.

As a result of Apache’s shift to horizontal drilling with multi-stage completions, horizontal wells drilled in the last three years — all successful — now account for about half of Apache’s Central Region production which totaled about 40,000 boe net per day at year-end 2011. “With this growth step, we expect to more than triple the pace of our operated activity in the multi-play fairway of combined Apache and Cordillera acreage during 2012,” Farris said.

Darby Releases New Advanced Bending Measurement System

Darby Equipment now offers AccuBend, a rugged and reliable bending measurement system that is accurate to within 1/10 degree.

This model uses advanced technology and is designed for ease of use to save time, money and headaches. It features two magnetic base transmitters that hold tight to the outside wall of the pipe and emit serialized radio frequencies to a single receiver mounted at the operator’s stand. The relative angle is set by a simple flip of the switch on the receiver and you’re ready to bend. Other features are a constant digital readout, automatic shutoff to preserve battery life and a compact, self-con-tained carrying case.

Contractors love the Darby bending measurement sys-tem because it virtually eliminates the need to climb onto pipe, it keeps the work moving ahead to save time, and one Darby AccuBend model is good for bending all pipe sizes. Check it out at www.darbyequip.com.

ConocoPhillips Announces Executive Appointments

While the ConocoPhillips works to complete a new strategic repositioning, the company announced on Jan. 11 additional appointments to the executive management teams for the two energy companies that will be created when the changes are finished, expected in the second quarter of this year.

Phillips 66, the future independent downstream com-pany, named C.C. (Clayton) Reasor as vice president of investor relations, strategy and corporate affairs. The new ConocoPhillips, an independent, pure-play exploration and production company, named Ellen R. DeSanctis as vice president of investor relations.

Reasor has more than 30 years of experience in the oil and gas industry. He began his career with Phillips Petroleum Co. and has held positions of increasing respon-sibility including president of U.S. marketing. Reasor is currently vice president of corporate and investor relations for ConocoPhillips.

“Clayton has a wealth of knowledge and experience that will help us advance our strategy to grow Phillips 66 into an industry leading downstream company,” said Greg Gar-land, designated chairman and CEO for Phillips 66, which will have leading businesses in refining, marketing, mid-stream and chemicals.

DeSanctis joins ConocoPhillips having most recently served as senior vice president of corporate communica-tions for Petrohawk Energy in Houston. She has more than 30 years in the oil and gas industry, including 15 years leading integrated corporate communication programs and investor relations.


Darby’s new AccuBend system is suitable for bending all pipe sizes.

“Ellen knows our company, she knows our stakeholders and she is a proven leader in our industry,” said Ryan Lance, designated chairman and CEO of the future ConocoPhillips. “Her leadership will help us connect with investors as we establish a unique type of independent upstream company.”

ConocoPhillips’ repositioning is subject to market con-ditions, customary regulatory approvals, the receipt of an affirmative ruling from the U.S. Internal Revenue Service, the execution of separation and intercompany agreements and final board approval.

Mohawk Council and Niagara Gas Transmission Agree to Land Use Deal

During an official ceremony on Cornwall Island, On-tario, the Mohawk Council of Akwesasne (MCA) welcomed representatives from Niagara Gas Transmission Ltd. (NGTL), an Enbridge company, to the Tri-District Elders Centre on Jan. 20 to officially mark the payment of $1 million to use tribal land as a pipeline route.

The MCA and NGTL have signed an agreement that committed to a one-time infrastructure-related payment of $1 million and ongoing annual payments of approximately $100,000 for the next 20 years for the use of the land in which the NGTL pipeline runs.

The agreement signed between the MCA and NGTL is the result of years of work that demonstrates the commit-ment by both parties to work together and build a strong relationship for a bright future.

“Akwesasne has been engaged in a process to define and redefine its relationship with external agencies and govern-ments that recognizes our jurisdiction and decision-making

authority to determine how our lands will be utilized for the benefit of the Mohawks of Akwesasne,” said MCA grand chief Mike Kanentakeron Mitchell.

MCA Kanatakon district chief Larry King added, “The MCA hopes to build a strong relationship with the NGTL that is based on a foundation of cooperation, mutual trust and respect and this agreement reflects that relationship.”

NGTL president Lisa Lawler reiterated the benefits of the relationship between the MCA and NGTL, calling it “one that I am extremely proud of.” She added that the agree-ment can be used as a model to demonstrate how working together in an open and transparent manner can achieve outcomes with mutual benefit for the MCA community and NGTL.

“Enbridge is committed to working with and devel-oping positive relationships with Aboriginal communi-ties throughout our entire operation,” said Guy Jarvis, president of Enbridge Gas Distribution. “This initiative is about more than economics — it will ultimately contrib-ute to a stronger and more prosperous community from a strong relationship based on mutual respect and a desire to work together.”

As part of the agreement, NGTL has agreed to work with the MCA to conduct an economic development study on the merits of the MCA commissioning and operating a natural gas distribution enterprise in its community.

Kawehnoke district chief Abram Benedict concluded, “We are pleased that the agreement contains provi-sions that will provide additional benefits and services to Akwesasne, such as exploring the distribution of natural gas to the community in the near future.”


Spectra Energy Secures Shippers for TEAM Pipeline Expansion

Spectra Energy Corp. is moving forward with plans to expand its Texas Eastern Transmission LP pipeline system. The company has reached binding agreements with two anchor shippers for its Texas Eastern Appalachia to Market (TEAM) 2014 project, an expansion of its existing Texas East-ern system to deliver additional emerging Appalachian shale natural gas supplies to diverse markets in the Northeast, Midwest and Southern United States.

These commitments provide sufficient market support to proceed with the development of the TEAM 2014 project. Texas Eastern will solicit interest from additional shippers through a binding open season, which ended Feb. 17.

TEAM 2014, with an estimated fourth quarter 2014 in-service date, reflects a fully scalable capacity expansion of up to 1.4 billion cubic feet (bcf) per day, including the volume of the two anchor shippers. Because Texas Eastern is expand-ing its existing pipeline system, the expansion project can be sized to meet the needs of the two anchor shippers as well as additional shippers that may be identified during the bind-ing open season. The company currently estimates the ex-pansion will result in a capital investment of approximately $500 million, which could potentially increase based on the results of the open season.

Interested shippers will have the opportunity to nominate transportation services from multiple existing and proposed receipt points in West Virginia and southwestern Penn-sylvania to multiple delivery points across the Northeast, Midwest and Southeast U.S. markets. Additional details will be included in the open season materials.

“We are pleased to reach agreements with the two anchor shippers for TEAM 2014 and expect additional interest from other shippers during the open season. This new project follows the successful TEAM 2012 expansion, which will go into service in fourth quarter this year and provide a total of 200 million cubic feet per day of new incremental capac-ity. Like TEAM 2012, this project is fully scalable to meet the transportation requirements of our shippers and offers sub-stantial flexibility and market access,” said Bill Yardley, group vice president at Spectra Energy Transmission, Northeast.

“The TEAM projects, along with our recently announced Ohio Pipeline Energy Network (OPEN) project, are key com-ponents in our approach to the Marcellus and Utica shale supply basins,” Yardley added. “Connecting these growing supply basins to the premium markets we serve is a win-win for Spectra Energy and our shippers.”

Plains All American Announces New Mississippian Lime Pipeline

Plains All American Pipeline LP plans to construct a new 170-mile pipeline to service the increasing Mississippian Lime crude oil production in northern Oklahoma and south-ern Kansas. This pipeline, in conjunction with the previous-ly announced Medford-to-Cushing pipeline conversion, is designed to provide approximately 175,000 barrels per day (bpd) of crude oil transportation capacity to the Cushing, Okla., market and is expected to be completed in mid-2013.

Plains All American also announced it has entered into a long-term agreement with SandRidge Energy to purchase SandRidge’s production from a multi-county area around the new pipeline system.

The Mississippian Lime pipeline will originate in Alfalfa County near Alva, Okla., and terminate at the company’s Cushing crude oil storage facility.



Can the United States reduce its reliance on foreign energy sources? According to a recent study, increased domestic pro-duction of natural gas and renewables will allow the country to be more energy independent over the next decade.

The Annual Energy Outlook 2012 (AEO2012) reference case released Jan. 23 by the U.S. Energy Information Admin-istration (EIA) presents updated projections for U.S. energy markets through 2035. The reference case projections in-clude only the effects of policies that have been implement-ed in law or final regulations.

“Our updated reference case projections show natural gas and renewables gaining an increasing share of U.S. electric power generation, domestic crude oil and natural gas pro-duction growing, reliance on imported oil decreasing, U.S. natural gas production exceeding consumption and energy-related carbon dioxide emissions remaining below their 2005 level through 2035,” says EIA acting administrator Howard Gruenspecht. “These projections reflect increased energy efficiency throughout the economy, updated assessments of energy technologies and domestic energy resources, the influence of evolving consumer preferences and projected slow economic growth.”

Some key findings:

Domestic crude oil production is expected to grow by more than 20 percent over the coming decade: Domestic crude oil production increased from 5.1 million barrels per day in 2007 to 5.5 million barrels per day in 2010. Over the next 10 years, continued development of tight oil combined with the development of offshore Gulf of Mexico resources are projected to push domestic crude oil production to 6.7 million barrels per day in 2020, a level not seen since 1994.

With modest economic growth, increased efficiency, growing domestic production and continued adop-tion of nonpetroleum liquids, net petroleum imports make up a smaller share of total liquids consumption: U.S. dependence on imported petroleum liquids declines in the AEO2012 Reference case, primarily as a result of growth in domestic oil production of over 1 million barrels per day by 2020, an increase in biofuel use of over 1 million barrels per day crude oil equivalent by 2024 and modest growth in transportation sector demand through 2035. Net petroleum imports as a share of total U.S. liquid fuels consumed drop from 49 percent in 2010 to 38 percent in 2020 and 36 per-cent in 2035 in AEO2012 (Figure 1).

U.S. production of natural gas is expected to exceed consumption early in the next decade: The United States is projected to become a net exporter of liquefied natural gas (LNG) in 2016, a net pipeline exporter in 2025, and an over-all net exporter of natural gas in 2021. The outlook reflects in-creased use of LNG in markets outside of North America, strong

domestic natural gas production, reduced pipeline imports and increased pipeline exports, and relatively low natural gas prices in the United States compared to other global markets.

Use of renewable fuels and natural gas for electric power generation rises: The natural gas share of electric power generation increases from 24 percent in 2010 to 27 per-cent in 2035, and the renewables share grows from 10 percent to 16 percent over the same period. In recent years, the U.S. electric power sector’s historical reliance on coal-fired power plants has begun to decline. Over the next 25 years, the pro-jected coal share of overall electricity generation falls to 39 percent, well below the 49 percent share seen as recently as 2007, because of slow growth in electricity demand, contin-ued competition from natural gas and renewable plants and the need to comply with new environmental regulations.

Total U.S. energy-related carbon dioxide emissions remain below their 2005 level through 2035: Energy-related carbon dioxide emissions grow by 3 percent from 2010 to 2035, reaching 5,806 million metric tons in 2035. They are more than 7 percent below their 2005 level in 2020 and do not return to the 2005 level of 5,996 million metric tons by the end of the projection period. Emissions per capita fall by an average of 1 percent per year from 2005 to 2035, as growth in demand for transportation fuels is moderated by higher energy prices and Federal fuel econ-omy standards. Proposed fuel economy standards covering model years 2017 through 2025 that are not included in the Reference case would further reduce projected energy use and emissions. Electricity-related emissions are tempered by appliance and lighting efficiency standards, state renew-able portfolio standard requirements, competitive natural gas prices that dampen coal use by electric generators and implementation of the Cross-state Air Pollution Rule.

The full AEO2012 report, including projections with dif-fering assumptions on the price of oil, the rate of economic growth, and the characteristics of new technologies, will be released in late spring 2012, along with regional projections.

Market Watch

Reducing U.S. Energy Imports EIA Projects Increased Energy Production and Efficiency to Reduce Reliance on Foreign Sources

The following oil and gas pipeline projects have been announced. Projects are in order of approximate starting date. All projects are for 2012 unless noted otherwise.

ARB Inc. was awarded a contract by Kern River Gas Transmission to install 9 miles of 8-in. gas pipeline in San Bernardino County, Calif. Headquarters is Primm, Calif. Superintendent is Terry Cooley. Approximate start date: Feb. 6.

Northern Clearing Inc. was awarded a contract by Price Gregory International Inc. for right-of-way clearing of approximately 63 miles of 8- and 24-in. pipelines in Marshall County, Ohio, and Brooke County, W.Va. Headquarters is unknown. The superintendent is Jim Junker Sr. Approximate start date: Feb. 6.

Northern Clearing Inc. was awarded a contract by Sheehan Pipe Line Construction Co. for right-of-way clearing of approximately 113 miles of 10-, 12-, 16-, 20- and 24-in. pipelines in Harrison, Marion and Monongalia counties, W.Va., and Greene and Washington counties, Pa. Headquarters is unknown. The superintendent is Dennis Bergman. Approximate start date: Feb. 6.

Dun Transportation & Stringing Inc. was awarded contracts by U.S. Pipeline Inc. for the following: 1) the stringing of approximately 12 miles of 42-in. pipe in Gaston, Rowan and Davison counties, N.C.; and 2) the stringing of approximately 10 miles of 42-in. pipe in Coosa and Randolph counties, Ala. Headquarters for both jobs is in the pipe yard. The superintendents are Greg Norman and John Zaruba, respectively. Approximate start date for both jobs: Feb. 1.

Sheehan Pipe Line Construction Co. was awarded a contract by Momentum for the installation of 2.39 miles of 10-in. pipeline, 14.45 miles of 12-in. pipeline, 49.64 miles of 16-in. pipeline, 20.34 miles of 20-in. pipeline and 31 miles of 24-in. pipeline in Harrison, Marion and Monongalia counties, W.Va., and Greene and Washington counties, Pa. Headquarters is in Idamay, W.Va. The Superintendent is Thelbert Barnes. Approximate start date: Feb. 1.

Indianhead Pipeline Services LLC was awarded a contract by Precision Pipeline LLC to perform foam services on 38,628 ft of 16- and 20-in. pipeline, 31,680 ft of 16-in. pipeline, 25,120 ft of 20-in. pipeline and 5,000 ft of 10-in. pipeline in Bradford County, Pa. Headquarters is Nichols, N.Y. The superintendent is Randy Rubenzer. Approximate start date: Jan. 26.

Midwest Underground Inc. was awarded a contract by ONEOK for the installation of 700 ft of 8-in. pipeline via directional drilling in DuPage County, Ill. Headquarters is in Naperville, Ill. The Superintendent is Shaun Tippie. Approximate start date: Jan. 23.

Price Gregory International Inc. was awarded a contract by Anadarko Petroleum Co. to install various lengths of miscellaneous diameter pipelines up to and including 20-in. pipelines in Loving, Reeves, Ward, Pecos, Winkler, Ector, Crane, Andrews, Midland, Upton, Brewster, Jeff Davis, Culbertson and Hudspeth counties, Texas. Headquarters is Kermit, Texas. The superintendent is Michael Phillips. Approximate start date: Jan. 23.

Dun Transportation & Stringing Inc. was awarded a contract by California Steel/Energy Transfer for the unloading and stockpiling of approximately 155 miles of 16-in. pipe in Ector County, Texas. Headquarters is in the pipe yard. The superintendent is Mike Bruce. Approximate start date: Jan. 20

Henkels & McCoy Inc. was awarded a contract by Spectra for the off-loading of 11 miles of 36-in. pipe from railcars in Franklin County, Pa. Headquarters is in Chambersburg, Pa. The Superintendent is Richard Hill. Approximate start date: Jan. 18.

Apex Pipeline Services Inc. was awarded a contract by Anterro Resources to install approximately 15,000 ft of 16-in. pipeline in Doddridge County, W.Va. Headquarters is Sedalia, W.Va. The superintendent is Cliff Frymier. Approximate start date: Jan. 16.

Associated Pipe Line Contractors Inc. was awarded a contract by Mark West Liberty Midstream & Resources for the installation of 11,267 ft of 12-in. pipeline in Washington County, Pa. Headquarters is in Washington, Pa. The superintendent is Kevin Berryman. Approximate start date: Jan. 16.

Rockford Corp. was awarded a contract by Williams Midstream for the installation of 7,800 ft of 24-in. pipeline in Susquehanna County, Pa. The headquarters is in Montrose, Pa. The superintendent is Mickey Langston. Approximate start date: Jan. 16.

Laney Inc. was awarded a contract by Troy Construction for road boring on 54.7 miles of 24-in. pipeline in De Witt, Victoria and Jackson counties, Texas. Headquarters is Victoria, Texas. The superintendent is Mike Dobbs. Approximate start date: Jan. 12.

Appalachian Pipeline Contractors LLP was awarded a contract by Piedmont Natural Gas to remove 3,200 ft of 10-in. natural gas pipeline and replace it with 3,200 ft of 8-in. natural gas pipeline in Davidson County, Tenn. Headquarters is unknown. The superintendent is Anthony Campbell. Approximate start date: Jan. 9.

Laney Directional Drilling Co. was awarded a contract by Boyer Construction to install 700 ft of 48-in. pipeline via directional drilling in Galveston County, Texas. Headquarters is

North American Pipeline Project Roundup

Listings Contributed by


on the jobsite. The superintendent is Kyle Orum. Approximate start date: Jan. 5.

Laney Inc. was awarded a contract by Troy Construction for road boring on 57.2 miles of 20-in. pipeline in San Patricio and Bee counties, Texas. Headquarters is Victoria, Texas. The superintendent is Mike Dobbs. Approximate start date: Jan. 16.

Letourneau Products Mfg. Corp. was awarded a contract by U.S. Pipeline Inc. for the following: 1) clearing, grubbing and matting for approximately 10.3 miles of 42-in. pipeline in Randolph and Rockford counties, Ala. Headquarters is unknown. The superintendent is Terry W. Maxon. And 2) clearing, grubbing and matting for approximately 12.1 miles of 42-in. pipeline in Gastonia, Rowan and Davidson counties, N.C. Headquarters is unknown. The superintendent is Mark A. Letourneau. Approximate start dates: 1) Feb. 1 and 2) Jan. 16.

Letourneau Products Mfg. Corp. was awarded a contract by Price Gregory International Inc. for clearing, grubbing and matting of approximately 30 miles of 24-in. pipeline in Luzerne County, Pa. Headquarters is Tunkhannock, Pa. The superintendent is Claude R. St. Pierre. Approximate start date: Jan. 23.

Letourneau Products Mfg. Corp. was awarded a contract by Otis Eastern Service Inc. for clearing, grubbing and matting of approximately 7 miles of 6-, 8- and 12-in. pipelines in Bradford County, Pa. Headquarters is unknown. The superintendent is Claude R. St. Pierre. Approximate start date: Jan. 5.

Minnesota Ltd. Inc. was awarded a contract by Enbridge Energy Inc. for anomaly digs in various counties in Wisconsin. Headquarters is Big Lake, Minn. The superintendent is Lloyd Pedersen. Approximate start date: Jan. 4.

Northern Clearing Inc. was awarded a contract by Meridien Energy LLC for right-of-way clearing for approximately 38 miles of 30-in. pipeline in Bradford, Sullivan and Lycoming counties, Pa. Headquarters is unknown. The superintendent is Duanne Kmieciak. Approximate start date: Jan. 9.

Snelson Cos. Inc. had been awarded a contract by PG&E for maintenance and hydro-test work on various sizes of pipeline in Northern and Central California. Headquarters is unknown. The superintendent is Jeff Elliott. Approximate start date: Jan. 16.

U.S. Pipeline Inc. was awarded a contract by Transcontinental Gas Pipe Line Co. LLC for the following: 1) install approximately 12.12 miles of 42-in. pipeline in Gaston, Rowan and Davison counties, N.C. Headquarters is Kings Mountain and Mooresville, N.C. The superintendent is Jim Jennings. And 2) install approximately 10.31 miles of 42-in. pipeline in Coosa and Randolph counties, Ala. Headquarters is Kellyton, Ala. The superintendent is Thad Hutchens. Approximate start date for both jobs: Jan. 9.

Welded Construction LP was awarded a contract by Williams Gas/Transcontinental for investigative digs on 30- and 36-in.

pipelines in Forsyth County, N.C. Headquarters is Perrysburg, Ohio. The superintendent is Joe Carter. Approximate start date: Jan. 3.

Miller Pipeline Corp. was awarded a contract by Williams Midstream to install 6.8 miles of 10-in. pipeline in Fayette County, Pa. Headquarters is Uniontown, Pa. The superintendent is Keenon Snow. Approximate start date: Jan. 3.

Price Gregory International Inc. was awarded a contract by Anadarko Petroleum Corp. to install 3 miles of 12-in. pipeline in Clinton County, Pa. Headquarters is Beech Creek, Pa. The superintendent is Mike Phillips. Approximate start date: Jan. 3.

Sheehan Pipe Line Construction Co. was awarded a contract by Mark West to install 30.9 miles of 10-in. pipeline and associated fabrication in Marshall and Wetzel counties, W.Va. Headquarters is Glen Dale, W.Va. The superintendent is Joe Parrish. Approximate start date: Jan. 3.


Want to see your project here? Send submissions to Associate Editor

Brad Kramer at [email protected] with the subject heading “Project Roundup.”


Consumer demand for energy continues to rise in North America, and one resource promises an abundant — al-

beit controversial — future. Natural gas production has booming potential because

of the advancements in accessing shale formations, but fears about the technology to do so pose a challenge to the industry. How those challenges are addressed will have a lasting effect on the natural gas and pipeline con-struction industries.

A wide array of advocacy groups are leading the pushback against misinformation and fear mongering associated with shale gas production, particularly with hydraulic fractur-ing. Dan Whitten, vice president of strategic communica-tions at America’s Natural Gas Alliance (ANGA), admits that the industry has concerns about the safety, but urges that more education is necessary. He says misinformation leads to “more of a fear-based than a science-based discussion.”

ANGA, which represents 30 of North America’s largest independent natural gas exploration and production com-panies, has sought to make the industry more transparent by having its member companies disclose the components of the fracturing fluid used at well sites through the website www.fracfocus.org, an industry-sponsored online database that recently reached 10,000 registered wells.

“We are working through every avenue we can to encour-age open discussion about the risks and benefits of our ener-gy choices as a nation on an informed, science-based level,” Whitten says. “ANGA member companies are passionate about ensuring our country takes full advantage of the vast

benefits that abundant natural gas offers our economy, our environment and our energy security. And, we are equally passionate about safe and responsible development — and making sure folks have the facts about how we do our work, the tremendous care that is taken, the oversight that exists and the benefits to the general public around greater use of natural gas in power generation and transportation. A key part of that commitment is clearly and consistently com-municating with the public to answer their questions.”

The Interstate Natural Gas Association of America (INGAA), which is comprised of 26 members that repre-sent interstate natural gas transmission pipeline companies in the United States and Canada, also promotes a broad approach to ensure a safe and reliable industry.

Although the concerns over producing natural gas from shale formations does not relate directly to INGAA, as its members transport, not produce, the natural gas, associa-tion spokeswoman Catherine Landry says the group is committed to the safe development and transportation of shale gas.

“An open public dialogue and stakeholder engagement is vital to securing broad-based support for natural gas supply and infrastructure development,” Landry says, “as are state, local and federal policies that balance appropriately the need for increased natural gas supply with concerns over the environment and other issues.”

With the vast natural gas — as well as some oil — reserves found in shale formations around the United States and Canada, the American natural gas resource base is far great-

Cracking the ShaleNatural Gas Remains a Driving Force in the Energy IndustryBy Bradley Kramer

er than thought a decade ago, Landry says. The Marcellus and Utica shale plays in the Northeast, the various forma-tions in the south-central part of the United States, with the Barnett, Eagle Ford, Fayetteville, Haynesville and Woodford regions, and the Bakken shale to the north are just a few of the reserves that could provide abundant, domestically produced energy for the next couple decades.

“Development of this resource base already is transform-ing the American economy, drastically enhancing the na-tion’s energy security and improving air quality,” Landry says. “Further natural gas development will bolster indus-trial expansion, create American jobs, and generate tax and other revenue for the local, state and federal government and benefit homeowners, businesses and other consumers of natural gas.”

Thanks primarily to two technologies — horizontal drill-ing and hydraulic fracturing — accessing shale formations for these energy resources has become more economical and, Whitten says, reduced environmental impact.

“Thanks to horizontal drilling, today’s average well site is just 30 percent of the size of its 1970s counterpart and can access 60 times more below-ground area,” he adds. “Continued technological advancements mean fewer wells recovering even greater reserves and creating less surface disturbance and waste.”

In producing shale gas, companies drill one vertical hole that can then branch out into several horizontal cuts once the correct depth has been achieved. This important ad-vancement reduces the overall environmental impact of drilling activities by giving access to more of the natural gas formation underground from fewer wells above ground.

With hydraulic fracturing, Whitten says, companies are able to tap into new supplies of natural gas with a process that takes place more than a mile below the earth’s surface.

“The process is minimally invasive and involves drill-ing a small hole, typically about 15-in. in diameter, which is lined with multiple layers of steel encased in cement to protect any fresh water supplies and allow for the safe ex-traction of natural gas,” Whitten explains. “Then pressur-ized water, sand and additives (less than 1 percent of the overall mixture) are used to create small, often millimeter-thick fissures in carefully targeted sections of the shale rock.


This releases the natural gas, allowing it to safely rise to the surface within the self-contained system. This new shale development is bringing new revenues, new jobs and training op-portunities to 32 states across the country, and stable, cleaner burning energy to Americans everywhere.”

Overcoming ChallengesIn 2010, shale natural gas account-

ed for 27 percent of total U.S. natural gas production, according to ANGA. This share will likely increase to 43 percent by 2015 and to 60 percent by 2035.

“Natural gas is underutilized in this country, with the most modern natural gas power plants running at just 42 percent of their capacity,” Whitten says. “That means we are ready now to fire up and provide do-mestic, low-cost and stable energy to

millions of Americans. Currently, prices are forecasted to remain steady for at least the next two decades. According to a new IHS study, these low, stable prices mean that on average, American consumers will save nearly $1,000 a year over the next three years in disposable income, and this number is expected to double in the next 20 years.”

One company that has been active in shale gas drilling is Chesapeake Energy Corp., which has a strong presence

This diagram shows how natural gas wells are drilled in shale formations, showing the depth of hydraulic fracturing and protection to water sources.

in Ohio and Pennsylvania. Michael Kehs, Chesapeake Energy vice president of strategic affairs and public rela-tions, stresses the importance of shale gas development.

“Shale gas development is changing both the energy and economic future of America,” Kehs says. “Through the advanced technologies of horizontal drilling and hydrau-lic fracturing, we are able to access natural gas from deep shale formations. The process of discovering and producing this natural gas is helping create a million new jobs in our country, promoting other business sectors — particularly manufacturing — and helping our country become more energy independent.”

In order for natural gas from shale to deliver on that promise, however, the industry must manage the risks and educate the public.

“We are committed to educating people about the safe and responsible practices we use every day to produce this vital resource,” Whitten says. “As part of that, we talk about the fact that all forms of energy comes with some level of risk. The key in our case is that we can manage

that risk appropriately through multiple layers of concrete and cement that separates the drilling process from wa-ter supplies. There are people out there who are not inter-ested in a fact-based conversation and who have engaged in fear mongering, and that presents some challenges. But again, when you talk to people about the science behind this process, and both the risks and the economic and environmental advantages natural gas brings, that outreach really has made a difference in communities in which we do our work.”

Another benefit of natural gas is its impact on the environment. Natural gas has 80 percent fewer nitrogen oxides emissions than the dominant electricity source (coal), and virtually no sulfur dioxide, mercury or par-ticulate pollution.

Despite the positive attributes of shale gas, a storm of controversy has surrounded its development and led to a number of campaigns to impose statewide moratoria on hydraulic fracturing because of alleged dangers to drinking water.


Vacuuming the Shale A Q&A With Ditch Witch on the Use of Vacuum Excavators in the Marcellus Shale

With all the drilling activity in the Marcellus shale, it’s no surprise that equipment manufacturers are seeing an uptick in business in the region. Dan Durkin, territory manager for Ditch Witch in western Pennsylvania, spends much of his time supporting oil and gas customers working in and around the Marcellus shale. The company’s vacuum excavators are particularly popular among drilling companies that use the machines to remove liquids from under and around drill rigs, as well as to locate utilities.

We asked Durkin to explain this trend and offer some advice in picking the right vacuum excavator for the job.

Why use vacuum excavators as opposed to other equipment?

Vacuum excavators equipped with reverse flow al-low the operator to collect and deposit liquid spoils into “frack” tanks without opening the hatch. Reverse flow, and other features on the machines we configure spe-cifically for drill pad maintenance, offer faster, cleaner operation and can be easily pulled from site to site. Vacuum excavators can also be used to uncover bur-ied utilities, without the risk of damage that backhoes, shovels and other hard excavation tools pose.

What effect on the environment do vacuum excavators have in shale drilling? Vacuum excavators make it easier for contractors to maintain the cleanest possible jobsite, which is obviously good for

the environment.

How is safety affected by the use of vacuum excavators on the jobsite? When locating utilities, vacuum excavation is safer than hard excavation methods. Ditch Witch offers the quietest vacuum

excavator available, which lends itself to a healthier work environment, while improving the ability to communicate on site.

What is the size/power range of these units available? Standard sizes of Ditch Witch vacuum excavators range from a 150- to 1,200-gallon spoils tank, horsepower ratings from

27-hp gasoline, 30-hp diesel and 60-hp diesel engines, suction from 540 to 900 cfm and pressures of 15 to 17 inches of mercury (inHg).

What are the differences of buying vs. renting a unit? Due to the environmentally sensitive work that vacuum excavators do, it is important to have a unit available 24/7, whether

actively in use or not. Many oil and gas contractors rent their equipment to achieve the desired availability, without the separate expenses and responsibilities associated with equipment maintenance, repair, etc. That being said, purchasing a vacuum excavator can provide the user a lower cash outlay while growing equity in the unit. Maintenance contracts and extended warranties, available from us at additional cost, can improve uptime and help manage owning and operating costs.


that impedes development could threaten the potential benefits of shale gas. We also need to be able to build the pipeline and other midstream infrastruc-ture necessary to allow the production to move to market.”

Natural gas is regulated on the federal, state and local levels, with states having the primary authority to regulate the extraction and use of natural resources within their boundaries.

“The geologic formations that retain oil and natural gas reserves are typi-cally located below impervious shale layers (often several thousand feet thick) that separate the formations containing water from those containing hydro-carbons,” Whitten says. “Because the geologic formations are highly vari-able, primary authority is given to state regulations that reflect local physical, economic and social conditions.

“There are a number of examples ranging from water availability and use, to porosity of the shale, to depth of the different shale wells, to depth of the

“The natural gas industry currently op-erates in 32 states, which has positive ram-ifications in all 50, but you needn’t look any farther than the Pennsylvania-New York state line to see how drilling mora-toriums affect communities,” Whitten says. “A study by Penn State found that by 2020, the natural gas community could bring to Pennsylvania more than $20 bil-lion in value added, $2 billion in state and local taxes and more than 250,000 jobs. In New York, where there currently exists a moratorium on new drilling, this growth is nonexistent. New York, like much of the rest of the country, is in dire need of new jobs and new revenues, and safely producing its own cleaner burning energy could be a massive boon to com-munities across the state.”

If states pass moratoria indiscriminate-ly, Landry adds, then the impacts could be far reaching in terms of energy pro-duction and economic vitality.

“In making decisions on various natu-ral gas issues in 2012, it is important that the president and Congress keep in mind the strategic importance of natural gas to America’s energy future, especially as it pertains to jobs, economic activity and energy security,” she says. “Public policy

The natural gas industry must ensure safety in accessing shale deposits and educate the public about the drilling and hydraulic

fracturing process.


groundwater where we are drilling. In all of these cases, we need folks on the ground with local expertise to conduct proper oversight.”

Building InfrastructureWhile drilling to access the natural gas in shale forma-

tions remains the primary focus in the industry, developing the infrastructure to transport the product to refineries and then to market is a growing concern.

“There have been a significant number of large projects built since 2006 that transport shale gas — witness the east to west projects out of the Barnett shale area,” Landry says. “There are many other examples.”

Right now, though, there’s a big push to build gathering lines to allow wells to be linked into existing transmission lines.

“Generally speaking, producers are the ones that fi-nance gathering lines, not the pipeline companies,” Landry adds. “Going forward, much of the midstream investment will be focused on redirecting pipeline flows to allow more gas to move into the line in the production basin, and also directing that gas to nearby markets.”

For example, instead of ship-ping natural gas from Louisiana or Texas to New York or New England, companies may find it makes more sense to alter or expand and build new lines to transport Marcellus gas directly to that region.

“On the pipeline side, a num-ber of projects are on the drawing board to bring Marcellus basin gas to market,” Landry says. “Utica development is a bit behind the Marcellus, but we are confident projects to allow supply to access markets will be built.”

While building gathering lines will be a focus in 2012, some large interstate projects have already been approved and applications either have or will be filed with regulators to build others.

“But it takes a couple of years for a pipeline to go from the planning stages to actually flowing gas,” she adds. “So some construction activity is al-ready in the works, and more is planned. One other trend is the move to build natural gas liquids (NGL) pipelines out of shale areas, particularly those rich in liquid hydrocarbons.”

As gathering and transmission pipelines are in the works, treatment facilities are seeing an increase in de-mand because of shale gas development, according to Bill Stokes, vice president of business develop for Kind-er Morgan, which offers a variety of treatment plant capabilities to ensure the natural gas meets the proper parameters for pipeline transport. These plants remove carbon dioxide and hydrogen sulfides, which can cause corrosion in steel pipe.

“Most shale plays have gas that is slightly out of spec for pipelines,” Stokes says. “We treat the natural gas for the

producer at the wellhead or gathering system before going into an interstate pipeline.”

Kinder Morgan provides turnkey solutions for treat-ment plants, and can install a plant in about three weeks, depending on the size and capacity.

Seeing the FutureEnsuring the longevity of the natural gas industry’s

involvement in the shale plays requires further innovation to increase environmental safety.

“Exciting innovations in all steps of the drilling process are being piloted by service companies and producers,” Whitten says, “including alternatives for the chemistry of fluids and hydraulic fracturing additives and new technolo-gies for water management and recycling, as well as new ways to further reduce the surface footprint of a well pad.”

Some natural gas producers are employing closed-loop water recycling systems, he adds. When water returns to the surface from the natural gas production process, solids are

separated in an onsite storage tank, which eliminates the need to dig and use an open reserve pit. The water is then reused in the production process, allowing for 100 percent recycling. Reuse also minimizes truck trips to and from the worksite. Many of the barrels of water can be reused over 100 times when properly recycled.

“There are numerous other innovations that reduce water use, cut the amount of water that needs to be disposed of and limits the effects of any accident that could occur on site,” Whitten says. “We expect to see more in-novations like these in the next few years as producers continue to look for less costly and more environmentally friendly forms of extraction.

Bradley Kramer is associate editor of North American Oil & Gas Pipelines. Contact him at [email protected].

The natural gas industry must ensure safety in accessing shale deposits and educate the public about the drilling and hydraulic fracturing process.

President Barack Obama placed another roadblock be-fore TransCanada’s bid to build a cross-country crude

oil pipeline from Canada to the Gulf Coast with his Jan 18 decision to deny the company a permit to move forward. TransCanada has announced it will reapply for the permit, despite the president’s decision.

The Keystone XL pipeline has been mired under bureau-cratic scrutiny for the past three years, but has worked closely with the state of Nebraska to find the most envi-ronmentally friendly route through the state. TransCan-ada has repeatedly stated that the pipeline would be the safest ever built and would provide thousands of jobs in the United States.

Despite Obama’s jobs council calling for an energy policy that includes expanded oil and gas drilling and infrastruc-ture, the president followed the State Department’s recom-mendation to deny the presidential permit on the grounds that the project does not serve the national interest, accord-ing to a State Department release.

“Since 2008, the department has been conducting a transparent, thorough and rigorous review of TransCana-da’s permit application for the proposed Keystone XL pipe-

line project. As a result of this process, particularly given the concentration of concerns regarding the proposed route through the Sand Hills area of Nebraska, on Nov. 10, 2011, the department announced that it could not make a national interest determination regarding the permit application without additional information,” according to the statement. “Specifically, the department called for an assessment of alternative pipeline routes that avoided the uniquely sensitive terrain of the Sand Hills in Nebras-ka. The department estimated, based on prior projects of similar length and scope, that it could complete the neces-sary review to make a decision by the first quarter of 2013. In consultations with the state of Nebraska and TransCana-da, they agreed with the estimated timeline.”

On Dec. 23, 2011, Congress passed the Temporary Payroll Tax Cut Continuation Act of 2011, which called for Presi-dent Obama to decide within 60 days whether the pipeline was in the national interest. The State Department deter-mined that time frame was “insufficient for such a determi-nation.” The department’s denial of the permit application does not preclude any subsequent permit application or applications for similar projects.


Obama Denies Keystone Permit

TransCanada to Reapply for Approval

By staff reports

Shortly after the decision was announced, TransCanada said it would reapply to gain permitting because of the positive industry support for the project in Canada and the United States.

“This outcome is one of the scenarios we anticipated,” says Russ Girling, TransCanada’s president and CEO. “While we are disappointed, TransCanada remains fully commit-ted to the construction of Keystone XL. Plans are already under way on a number of fronts to largely maintain the construction schedule of the project. We will reapply for a presidential permit and expect a new application would be processed in an expedited manner to allow for an in-service date of late 2014.”

TransCanada expects that consideration of a renewed ap-plication will make use of the exhaustive record compiled over the past three years.

“Until this pipeline is constructed, the U.S. will continue to import millions of barrels of conflict oil from the Middle East and Venezuela and other foreign countries that do not share democratic values Canadians and Americans are priv-ileged to have,” Girling says. “Thousands of jobs continue to hang in the balance if this project does not go forward. This project is too important to the U.S. economy, the Ca-nadian economy and the national interest of the United States for it not to proceed.”

TransCanada will continue to work collaboratively with Nebraska’s Department of Environmental Quality on determining the safest route for Keystone XL that avoids the Sand Hills. This process is expected to be complete in September or October of this year.

TransCanada has committed to a project labor agreement with the Laborers International Union of North America, the International Brotherhood of Teamsters, the United Association of Journeymen and Apprentices of the Plumb-ing and Pipefitting Industry of the United States and Canada, AFL-CIO, the International Union of Operating Engineers and the Pipeline Contractors Association. Any delay in approval of construction prevents this work from going to thousands of hard-working trades people.

TransCanada’s investment of billions of private dol-lars would create thousands more jobs in the U.S. manu-facturing sector. The company has contracts with more than 50 suppliers across the United States. Manufactur-ing locations for Keystone XL equipment include: Texas, Missouri, Michigan, Oklahoma, South Carolina, Indiana, Georgia, Maryland, New York, Louisiana, Minnesota, Ohio, Arkansas, Kansas, California and Pennsylvania. The bene-fits these companies and the people of their states continue to be delayed and the negative impacts will be felt, accord-ing to a company statement.

Girling adds that TransCanada continues to believe in Keystone XL due to the overwhelming support the project has received from American and Canadian producers and U.S. refiners who signed 17- to 18-year contracts to ship more than 600,000 barrels of oil per day to meet the needs of American consumers.

Industry BacklashLeading up to President Obama’s decision, energy indus-

try representatives were already criticizing the permit denial. The American Petroleum Institute (API) called the decision “an abdication of leadership” during a Jan. 18 conference call with media members scheduled just before the presi-dent’s official announcement. By that time, the rejection was already being reported by mainstream media outlets.

“As you know, the administration is announcing it is re-jecting the Keystone XL project,” says API president and CEO Jack Gerard. “It says the biggest shovel-ready project in America must be abandoned because there’s not enough time to complete the review.”

“This is not leadership. It’s a genuflection to extreme elements who somehow believe America will be stronger turning its back on secure supplies of oil the president’s own energy department says will be needed for decades to come.”

Gerard went on to accuse Obama of playing politics dur-ing an election year.

“We would like to hope that petty politics did not enter into this important decision,” Gerard says. “This is a pure abdication of presidential leadership. How can you say you’re for job creation, but set aside the largest shovel-ready project in history?”

Obama missed an opportunity to show he was for energy independence and job creation, Gerard says. The decision could have political backlash.

“The president may dismiss these energy realities and may even believe keeping his job is worth the cost of the thousands of jobs that won’t be created,” Gerard says. “But we don’t think most Americans will agree. They know America will need more oil. They see the benefits of importing more from Canada while also producing more at home. And they believe this energy can be developed and consumed responsibly.”

Citing the United States’ continued struggle to recover from one of the worst economic downturns in its history, Gerard wonders why the president would further delay a project that has already been delayed three years.

“Fourteen million Americans remain out of work,” Gerard says. “Yet the president is now telling us that procedural niceties are preventing him from granting a permit that could put thousands of people to work without spending a single taxpayer dollar?

“He is telling us that more than three years of multiple-agency review are insufficient to advance a project that could supply massive quantities of secure oil — when it is becoming more and more apparent that the security of our international oil supplies is under serious threat?

“He is blocking a multi-billion dollar oil infrastructure project stretching across five states the day after his own Jobs Council has suggested that such projects are critical to helping our economy improve?

“This is all almost too hard to believe,” Gerard concludes. “It makes you really question how serious the president is about job creation. We have to ask, Mr. President, what are you thinking?”

Gerard called the decision “deeply disappointing,” but asserted that the API and other industry stakeholders would work with Congress to gain bipartisan support for the Keystone XL project to move forward.

“We will consider all legal and legislative options,” Gerard says. “This is clearly in the best interest of this country. We will continue to engage in educational outreach and get the message to the administration. This is a big national security decision. We believe there will be big political consequences to this decision. There are a number of Democrats that are not happy with this choice.”

Despite any attempt to punt this decision beyond the 2012 presidential elections, Gerard says the Keystone XL project will loom at the top of political discussions for the next 10 months.


The use of composites can be dated back to 1500 B.C. when the Egyptians mixed mud and straw to fabricate

large bricks that were superior in strength to other building materials of that time. It wasn’t until the 1930s that fibers and plastics began being combined to create strong, light-weight material. The demand for lighter weight materials in World War II helped bring this new composite technol-ogy into production by using fiberglass as an alternative to heavier materials for military aircraft. Twenty years later, carbon fiber, specifically Rayon, began to be combined with better polymers, providing an even stronger composite sys-tem. Innovation and research continue to improve both the polymers and reinforcing fibers used in items as simple as a set of golf clubs to the F-117 stealth aircraft.

Many industries have adapted composites, specifically fiberglass and carbon fiber systems, to fit the needs of a specific application in the industry. Pipeline rehabilitation has greatly benefitted from composite repairs and contin-ues to trust this technology to effectively repair pipelines and pipeline components. It wasn’t until 2006 that the ISO 24817 and ASME PCC2 Article 4.1 standards were created, dedicating themselves to the use of composite materials to repair and rehabilitate pressure-containing equipment. Like various other repair methods, such as steel sleeves and clamps, composite repairs are forced to undergo a rigorous vetting process to prove their strength and verify industry compatibility.

The Beginning of Composite Pipeline RepairThe pipeline industry’s methods for repairing aging or

damaged pipelines were bulky, expensive and difficult to install. The repairs needed to be faster, more reliable and easier to install. In the 1990s, companies determined that composite materials could meet the need proposed by the pipeline owners and maintenance providers. They could provide solutions for aging pipelines as well as preparing the way for a new composites industry. Because of the in-crease in the number of composite repair companies in the market, each manufacturer is required to innovate different products and solutions to meet more of their customer’s needs at more competitive prices.

Installers of steel sleeves, clamps and injection systems currently use these methods because according to many in the industry, they are the only alternative to full replace-ment of that section of the line. Oftentimes, these applica-tions are large, heavy, take more manpower to install and are more expensive. To the pipeline owners and mainte-nance providers, the ideal repair system would include the

following benefits: adding significant strength back to pipe-line, minimal manpower to install, fast installation time — low down time and no maintenance after installation — and long-term repair.

Citadel Technologies designs repair kits with these con-cerns in mind, aiming to provide the best products and services possible to their customers. Although composites have proven to be an effective repair method in the indus-try for the past 20 years, there is still a strong reluctance to accept composites as a viable and successful repair method.

The Battle for Industry AcceptanceBecause of the substantial claims made by composite

manufacturers, pipeline owners are reluctant to use this new repair method. This is likely due to the risk and liabil-

ity assumed if a failure was to occur. This reluctance has worked to the pipeline owner’s advantage because it has required the composite repair manufacturers to provide in-creasing levels of testing to prove that their materials and designs are able to meet the needs of the industry. This pro-cess, in itself, has separated the pack of composite repair manufacturers, proving the long-term players and those willing to compromise material and design quality.

To prove the performance capabilities of a repair system, a pipeline owner may request that tests be preformed on site or under their supervision so they can precisely monitor every aspect of the repair. Citadel Technologies was asked to participate in a test for a gas company on a 24-in. line. In this case, the customer requested a full-scale rupture test on an area with mechanical damage that was approximately 80 percent of the remaining wall and 4 in. long (Figure 1). The repair system was designed to be stronger than the pris-tine base pipe, which would cause rupture outside of the repair area. Figure 2 shows the pipe after pressurization to rupture, which was approximately 1,170 psi.


All Wrapped UpThe Evolution of the Composite Repair IndustryBy Amanda Hawkins and Roger Walker

Figure 1: A 4-in. by 80 percent wall loss flaw.


Choosing a Dedicated Composite Repair Manufacturer

Successful industry experience and/or third-party reviewed test programs are a requirement in proving the capabilities of a repair system. Citadel Technologies specializes in high temperature and odd configurations. Many complex appli-cations of Citadel’s products can be found throughout the world. For example, a 20-in. diameter high temperature pet-rochemical system (Figure 3) suffering from a weld seam leak was repaired using its High Temperature Ambient product line. The system was running at approximately 200 F and 450 psi. The line was repaired quickly and easily, without shutting down operation (Figure 4).

It is crucial for a composites manufacturing company to comply with industry standards such as U.S. DOT regulations, ASME and ISO standards. These standards are written and reviewed by panels of experts in the field, specializing in practical application as well as scientific research. Although the standards are in a constant state of review and improvement, it is a priority for each mem-ber of the review committee to keep the design criteria safe and conservative.

Citadel Technologies has been involved with numer-ous third-party testing programs associated with Pipeline Research Council International, Stress Engineering and the University of Tulsa (Okla.). A recent test program was performed on the repair of dents on welds, which is highly applicable to the pipeline industry. The study reviewed the viability of composite repairs to rehabilitate a line with a plain dent over straight pipe, a girth weld and an electrical resistance weld (ERW). With the appro-priate design and proper installation, a composite repair significantly lowers the strains on the base pipe, extend-ing the life of the line significantly. Figure 5 below shows a plain dent to be repaired and Figure 6 shows the pipe after the repair was made.

Citadel’s products have also been used in test programs researching the viability of using composites for underwa-ter repairs, repairs in seismically active areas and as soft crack arrestors.

Because composites are currently not accepted as common repair methods in some industries, repair manufacturers should be willing to provide a substantial degree of educa-tion to their customers. They should be willing to explain the ASME and ISO standards to further prove the capabili-ties of composite repairs. Armed with the knowledge of the industry standards and experimental data, confidence in composite repairs will expand the applications and overall market for all repair manufacturers. This will also allow man-ufacturers to utilize the expertise of experienced engineers to expand research on non-standard applications.

Composites have proven themselves in various indus-tries and applications, but more opportunity still awaits. Working together as an industry will drive further inno-vation allowing new opportunities and applications to be explored.

Amanda Hawkins is manager of engineering services and Roger Walker is president and CEO of Citadel Technologies.

Figure 2: Pipe rupture outside of composite repair.

Figure 3: High temperature Y before repair.

Figure 4: High temperature Y after repair.

Figure 5: Plain dent.

Figure 6: Plain dent after repair.

Proper evaluation of external corrosion is critical to de-termine the reason the corrosion occurred. Many times

external corrosion is blamed on lack of cathodic protection (CP), yet most times it is not the problem. Proper evalua-tion of external corrosion includes using several methods to determine why external corrosion exists even though NACE and other international criteria are met for cathodic protection at the site. Pipelines continue to have external corrosion issues because some do not have a good under-standing of the true reasons for external corrosion.

Case histories will be presented that discuss why coated pipelines with “adequate” cathodic protection continue to have external corrosion. While in other cases, the CP may not be adequate, according to the various standards, but no corrosion is found. The case histories will show some of the proper techniques used to evaluate external corrosion to determine why the corrosion existed.

Causes of External CorrosionDisbonded Coatings: If a pipeline coating loses adhesion

to the pipeline, this is referred to as a disbonded coating. The most significant external corrosion problem on coated and cathodically protected pipelines continues to be that of disbonded pipeline coatings that allow water to penetrate between the coating and the pipe and have no path for CP current to reach the pipe’s surface. All coatings can and will disbond for various reasons. Poor application procedures, soil stress, temperature and a variety of other reasons can cause coatings to disbond.

All coatings must have good dielectric strength when properly adhered to the pipe. When disbondment occurs and water penetrates between the coating and the pipe, certain types of coatings will shield the CP current while others have a proven field history of not shielding in these cases. Coatings may shield CP current in some situations and not in others. (See case histories 1 and 2 on Page 30.)

The relative tendency of pipeline girth weld coatings to shield CP current was studied in the laboratory. A key

consideration should be “Will the coating shield CP if the bond fails?’’ However, all coatings experience some disbondment and, therefore, the behavior of a disbond-ed coating is important in the overall performance of a coating system. Even with adequate cathodic protection, corrosion can occur under most disbonded coatings.

At least one in-line inspection (ILI) tool can now find disbonded coating.

Holidays and Coating Damage: If holidays or damage oc-cur during the coating application, during construction or burial of the pipeline, these areas can become spots where corrosion can occur. If adequate CP is applied, these areas will be protected.

If excessive CP is used, cathodic disbondments can oc-cur at these holiday sites. Some adhesion of some coatings will not withstand the rigors of the electrochemical process occurring at the cathode (pipe surface). Using more and more stringent criteria trying to meet a polarized minus-850 mV or more negative potential at all sites on the pipeline system may cause more cathodic disbondment.

Slightly more CP may be required, but no significant corrosion will occur on the pipelines at holidays when adequate CP is available to the holiday.

Holidays should be located and repaired as the pipe is being installed in the ditch, but a proper repair with the proper repair material must be performed. Many times the repair material will lose adhesion and may shield the CP allowing corrosion to occur. If a pipeline coating is adhered properly to the pipe surface and remains that way for the life of the pipeline, external corrosion is typically not an issue.

If the coating is damaged in such a way that a disbondment occurs — even without an apparent holiday — and water pen-etrates, CP shielding can become an issue. This is a particular concern for coatings with PE or PP backings such as three layer systems, shrink sleeves and solid film backed tapes.

AC and DC Stray Current Interference: Corrosion caused from AC or DC stray current interference can be very rapid,


Coat of ProtectionPipelines and External Corrosion

By Richard Norsworthy and John Strong

causing significant damage to metal surfaces from which the current discharges into the electrolyte. This type of corrosion will cause failure long before the design life of the system is reached.

If not detected and corrected quickly, the interfer-ence will result in leaks and potential explosions and environmental disaster. This corrosion is usually eas-ily detected through various surveying methods such as close interval or direct current voltage gradient sur-veys. Even annual surveys should give some indications that would lead to further investigation to determine if interference exists.

This is a particular problem on new, well-coated pipe-lines that are not immediately surveyed and cathodically protected after installation. Case History No. 3 shows a new FBE-coated pipeline parallel to several other systems that had impressed cathodic protection. This line was not properly bonded to the existing CP system and the corrosion occurred in less than one year at several sites along the pipe.

Shielding From Other Materials: Shielding can be caused from materials that are around a pipeline other than coat-ings. During the design phase of the pipeline it is critical not to use materials that will cause CP shielding. Some of these materials are solid film, non-conductive rock shields, various plastic construction materials not removed from the pipe or ditch, high-resistant sand or rock backfill, metal structures in proximity, reinforced concrete structures and other metal structures that may pick up the CP current intended for the pipeline.

Inadequate Cathodic Protection: These days, this is the least likely cause of external corrosion on cathodical-

ly protected and coated pipelines. With the use of ILI tools and ECDA, the true causes of external corrosion are now being proven. If companies, government agen-cies and contractors will spend more time training their employees on the proper evaluation techniques for determining the cause of external corrosion, the indus-try will find that inadequate CP is not the likely cause of corrosion.

Case HistoriesCase History No. 1: Coal tar-coated pipelines have per-

formed well in some environments while performing poorly in others. The failure mode of some coal tar coat-ing allows CP to be effective through cracks and pores in the coating, even when disbondment occurs. In this case, the coal tar was deteriorated and disbonded enough that the CP current could be effective. There was corrosion from previous shielding or inadequate CP, but as the high pH of 10 indicates adequate CP is now being allowed to protect the pipe through the disbonded coating. (See Photo No. 1.)

The cathodic protection “ON” potentials at this site were in a range of minus-500 mV to minus-600 mV. Polarized potentials were in the range of minus-350 mV to minus-450 mV. Native potentials were in a minus-200 mV to 300 mV range.

Case History No. 2: Photo No. 2 shows a 12-in. gas line that was coated with coal tar in the 1960s. The disbonded coal tar has been removed for a leak investigation. The po-larized CP potential of the pipeline ranged from minus-650 mV to minus-900 mV and the pipeline had a native poten-tial of minus-450 mV, so the line passed the 100 mV criteria for adequate CP.

The external pitting corrosion and leak that was found under the disbonded coal tar had a pH level of 3. The cor-rosion on the pipeline spans from 3 o’clock across the top of the pipe to the 9 o’clock position. The corrosion followed the same spiral pattern as the coal tar’s outer wrap. The pitted area of the pipeline had an average of 75 percent wall loss and one location with 100 percent wall loss. The disbonded coal tar shielded the CP current and the electrolyte under the coating disbondment formed a large corrosion cell.


Photo No. 1: Disbonded asphalt coating that did not shield the CP current because the coating was deteriorated and cracked enough

to allow current through the coating, therefore a high pH and minimal corrosion under the coating.

Photo No. 2: Disbonded coal tar coating, which shielded CP currents. Significant pitting in this area because of the CP shielding,

not lack of CP.


Case History No. 3: When a new pipeline is installed in an area where impressed CP is being used on other systems, the potential for corrosion from stray currents exists. Companies must perform proper surveys to deter-mine if these problems exist immediately after the new pipeline is installed.

Photo No. 3 shows the results of such an interference problem. The new FBE-coated pipeline was not properly bonded into the existing impressed current CP systems. This corrosion developed in less than one year.

Case History No. 4: Shielding can occur from a variety of other materials and components around a pipeline. Some of these shields can be man-made or natural.

Photo No. 4 shows the results of a large rock sitting on top of an FBE-coated pipeline shielding the CP. Even though there were other areas that had blistering of the FBE, there was no corrosion because there was no shielding of the CP current by the FBE. The criterion used for this pipeline at

this time was an “ON” minus-850 mV without consider-ation for IR (except when warranted).

Photo No. 5 shows the typical results when disbonded or blistered FBE is found. The pH is typically from 9 to 12 with little or no corrosion found. Sometimes the steel is discol-ored, but with no metal loss.

ConclusionsIn today’s culture of coating and cathodically protect-

ing pipelines, the real cause of external corrosion is sel-dom that of inadequate cathodic protection. Therefore, cathodic protection criteria are not the most important issue when considering NACE SP0169 and external corro-sion control. These conditions are the same in all coun-tries around the world as indicated in the variety of papers written about external corrosion on coated and cathodi-cally protected pipelines.

Pipeline coatings that shield cathodic protection are the major cause of external corrosion on coated and cathodi-cally protected pipelines. AC and DC interference is the most rapid and dramatic corrosion problem (especially at local holidays). However, proper monitoring and preven-tive methods are effective in controlling these problems. Preventing cathodic protection shielding from other materials besides coatings is also a very important issue when designing and installing a pipeline. Properly repair-ing holidays and damaged coatings with repair material that is compatible with CP and the existing coating is criti-cal to reduce the chance for shielding from the repair coat-ing and to limit the amount of cathodic protection required for the pipeline system.

If those responsible for corrosion control will prop-erly evaluate the true reasons for external corrosion, we find that many conditions are present that cause external corrosion other than inadequate CP. Once we know the true cause of external corrosion, we can then find the most economical and reasonable solutions to prevent future external corrosion problems.

Richard Norsworthy is technical advisor and consultant, NACE International corrosion specialist and instructor, and John Strong is in technical sales for Polyguard Products Inc., of Ennis, Texas.

Photo No. 3: Rare external corrosion on FBE-coated pipeline caused from DC interference.

Photo No. 4: Corrosion on FBE-coated pipeline from shielding of the CP by a large rock on top of the pipe.

Photo No. 5: Typical results when evaluating disbonded or blistered FBE coating. The pH of the water under the FBE at this site was 12

indicating that CP currents were not shielded.

Hydraulic excavators play a vital role in the pipeline construction industry. Various attachments allow these

versatile machines to dig, load, lift and grab. While com-pact excavators have gained a larger share of this market in recent years, heavy excavators continue to provide pipe-line contractors with the mechanical muscle needed for a variety of tasks.

While you may own at least one excavator, there will be times when a project calls for additional machines, a larger machine, a special machine or a special attachment. Or, you may be working away from your home base and wish to source equipment locally rather than transport-ing it over long distances. In these cases, it’s important to know your needs — and your options — before contacting a heavy equipment dealer or rental company.

Big Rentals

Know Your Needs Before Renting a

Heavy Excavator for Your Next Project

By Doug Zoerb


Start by thinking about the type of excavator you will need. The most common type is a crawler excavator with a conventional tail swing configuration. These machines are most often used for land clearing and general excavation, such as trenching. They are usually found on residential and non-residential building sites and on non-building construction projects such as pipelines and rights of way, among others.

Reduced tail swing excavators are gaining favor on proj-ects in congested urban areas and on roadways. These ma-chines offer a reduced tail swing radius that allows them to work in one lane of a street or highway without block-ing traffic in the adjacent lane. In some cases, digging and lifting performance is better or equal to a conventional tail swing excavator in the same size class.

Wheel excavators offer the ability to move quickly and easily from one place to another within the jobsite or work zone. This makes them ideal for lengthy street and high-way projects and for utility installation in large residential, commercial and industrial developments.

Super long reach (SLR) crawler excavators are designed for specialty applications such as dredging canals, cleaning ditches and creating retaining ponds for storm water runoff.

Specify Bucket Size, Machine WeightOnce you know the type of excavator you will need, your

next decision concerns machine weight and bucket size. For trenching work, choose a bucket that is the width of the trench you need to dig. Then size the excavator based on soil conditions, length of the trench and desired produc-tivity. In dense or tough soil conditions, a larger excavator will provide greater breakout force and improved produc-tivity. In sandy or loam soils, the smallest excavator that can handle the bucket size required is acceptable.

Remember that soil conditions may not be uniform throughout the trenching project. Choose an excava-tor that can handle the toughest conditions that may be encountered. In most cases, an excavator one size larger than the minimum size needed will provide greater per-formance and productivity, resulting in faster completion of the work.

While bucket width is critical for trenching, bucket capacity is the key factor in loading work. Choose a bucket capacity that is matched to the trucks you are loading, site conditions and the density of the material being loaded.

With a properly sized bucket, an excavator should be able to load an off-road truck in five to six passes, and no more than one truck should be waiting to be loaded at any time. On a typical jobsite, a smaller excavator should easily be able to keep two trucks busy. However, if your project requires you to use more than two trucks, a larger excavator may be required, depending on the haul distance.

Finally, don’t forget about lifting capacity. In trenching applications, the excavator is often required to reposition a trench box, which can typically weigh up to 12,000 lbs. Remember that an excavator is least stable when lifting over the side, so if a trench box must be removed and placed alongside the trench, the excavator must have enough lift-ing capacity over the side to accomplish this. Ask the equip-ment dealer or rental center to provide you with a lift chart, which is usually included in the machine specifications and/or operator’s manual.

Pay close attention to teeth and side cutters on the bucket you select for your project. For tough materials like asphalt or clay, choose those that are capable of standing

up well to the material being excavated. Teeth and side cutters are the most costly components on the bucket, so using items of the proper hardness can save expense over time. Remember that side cutters prevent wear and damage to the side of the bucket (for which you may be charged) and make it easier to cut through harder and more dense materials.

Other than buckets, breakers are one of the most com-monly rented attachments. If you don’t need a breaker on a continual basis, it is likely to be more cost-effective to rent an excavator and breaker for a month rather than purchase the breaker itself. Other frequently rented excavator attach-ments include clamps (or thumbs) and grapples, which are often used for land clearing.

Be Ready to RentHere are some additional tips when planning to rent a

heavy excavator:If you rent from a heavy equipment dealer, you will be

required to show proof that you carry a general liability insur-ance policy. Typically, these so-called blanket liability policies provide a minimum of $1 million in coverage for any prop-erty damage caused by you or your employees. Be prepared to provide the dealer with a copy. If you don’t have your own policy, some rental outlets may sell liability insurance that covers their product during the term of the rental.

While any mechanical failures not caused by abuse are usually covered by the dealer or rental outlet, check to see who is responsible for routine maintenance during the rental period. In most cases, the renter is responsible for changing engine oil and maintaining other fluids during the rental term. However, a heavy equipment dealer may agree to perform routine maintenance for an additional fee.

If you have your own shop, it will be less expensive to perform these routine maintenance items yourself. When done by the dealer, routine maintenance can usu-ally be performed in the field in order to minimize machine downtime. In all situations, the renter is responsible for performing regular daily maintenance such as checking oil and coolant levels.

Review the condition of the excavator before you leave the dealer or rental outlet. The dealer would much rather take care of a problem in their shop than fix it in the field. Be sure you understand all the terms in the rental agree-ment before you sign it.

The cost of transportation to the jobsite is normally an extra charge billed to the renter. To reduce costs, you may wish to arrange for your own transportation.

Be aware that excavators with new interim Tier 4 engines require the use of ultra-low-sulphur diesel fuel contain-ing less than 15 ppm of sulphur. In addition, some interim Tier 4 engines using EGR technology may require the use of specific, high-quality engine oil and servicing of the diesel particulate filter (DPF). Engines with selective catalytic re-duction (SCR) will require periodic fill-ups of diesel exhaust fluid (DEF). Check with your dealer or rental outlet regarding availability of these products and services in your area.

Finally, be aware that heavy equipment dealers often provide discount pricing on rental machines. If you rent an excavator for several months and decide to purchase it, some or all of your rental payments may be applied to the purchase price. It’s worth looking into.

Doug Zoerb works in public relations for Two Rivers Marketing, based in Des Moines, Iowa.

The most recent Common Ground Alliance (CGA) DIRT report shows that when an excavator calls

for a locate there is less than a 1 percent chance there will be damages. Of the incidents that do take place, 38 percent have a root cause of “excavation practices not sufficient.” Safe excavation practices prevent inju-ries to excavators and damage to pipelines, so everyone involved has a vested interest in doing things the right way.

As we all know one of the primary goals for the Pipe-line and Hazardous Materials Safety Administration (PHMSA) is to work with both pipeline operators and excavators to improve excavation safety, which is why they are big promoters of the CGA. The CGA is com-prised of representatives from all stakeholder groups, and works to protect North America’s buried pipelines and cables, as well as to help excavators dig safely.

Now in its seventh year, the CGA Excavation Safety Conference & Expo brings together over 2,000 stakeholders from throughout the industry to share ideas, learn from the experts, and gather information on industry trends and tech-nologies. In 2011, attendees represented 47 states, 6 Canadian Provinces, and nine other countries. The conference features more than 50 educational conference sessions developed and presented by industry experts, including several presented by PHMSA. Sessions focus on current issues and topics related to safe excavation and damage prevention.

In addition to conference sessions there will be a tour with demonstrations of the new Southwest Gas Operations and Training Center. The tour will highlight the state-of-the-art equipment, processes, and tools that Southwest Gas uses for training.

Here is a sampling of some of the sessions that will be held at the conference.


Uniting the Industry in Preventing Damage and Saving Lives


Developing an Excavation Safety CulturePresented by Lee Travis, HSE coordinator, TransCanada Pipelines, and Peter Buchanan, manager-pipeline maintenance projects, TransCanada Pipelines

Why do some excavation organizations perform better than others? What do they do that drives excavation safety performance? Could it be the strength of an organization’s excavation safety performance lies within the strength of its safety culture? We know there is no silver bullet to improving excavation safety or to establishing a world class excavation safety culture, but there are ways to improve. This session will outline and discuss multiple examples of excavation cultural elements that can be implemented to enhance people’s ability to build an excavation safety culture within an organization.

Importance of Analyzing, Reporting and Repairing Pipelines DamagedPresented by Amanda Hawkins, Citadel Technologies, and Roger Walker, Citadel Technologies

Pipelines are frequently damaged during excavation, which can result in a scratch, dent, gouge and, commonly, a mixture of the three. These defects are dangerous and costly, leaving the workers exposed to dangerous leaks or possible explosions while working around the pipelines/pipeline components. Various tests have shown that these defects cause areas of increased stress in the material — stress concentrations or stress risers — that could cause the substrate material to exceed yield strength, have significantly lower fatigue life or cause a complete through wall defect. Reporting these defects can allow the proper analysis and repair to be performed while the pipe is uncovered, avoiding additional excavation costs and personnel hazards. Repairs can be made using various options, including grinding out crack/gouge, metallic repairs and non-metallic repairs.

Safe Urban Pipelining: What Can Go Wrong?Presented by Bruce Jamer, director of operations, Kinder Morgan, and Rob Hadden, manager, damage prevention and public awareness, Kinder Morgan

Communication is a key to prevention. Many U.S. and Canadian companies operate transmission pipeline infrastruc-ture in areas where right-of-way may not be obtainable (under public roads etc.). The Trans Mountain Pipeline, operated by Kinder Morgan Canada in Burnaby, British Columbia, was struck and ruptured by a contractor excavator in 2007. The resulting oil spill impacted a residential neighborhood, attracted widespread media coverage and triggered a mas-sive cleanup on both land and water. Hear about the incident, response and lessons learned. Learn about the regulatory approach to enforcement and effective enhancements, reducing the likelihood of a future pipeline strike.

TransCanada’s Excavation Specification: An Effective Strategy for Ensuring Safe Ground Dis-turbances with ContractorsPresented by Brad Watson, pipe integrity specialist, TransCanada, and Rod Egert, manager, Keystone facilities safety, Keystone Pipeline

TransCanada, with a commitment to being an industry in excavation safety, has developed an excavation specifica-tion based on company and industry best practices. This new specification, when applied to contract agreements, helps ensure contractors plan and conduct safe ground disturbances in alignment with TransCanada’s minimum requirements. This session will showcase TransCanada excavation specification and provide insight into how it has helped create effec-tive contract agreements while achieving safe ground disturbances.

Gas & Oil Pipeline Integrity and Public Safety SummitPanel discussion sponsored by Celeritas

Join Celeritas in discussing how it helps companies address RP1162 compliance-related requirements through effective measurement, reports and enhanced compliance activities to address specific stakeholders, combining public awareness with other forms of data to make for a better overall program and more.

Public Awareness, Dealing with Media & Crisis CommunicationPresented by Rebecca Virden, manager-public relations, CenterPoint Energy

Learn about crisis management and how to respond to the media. Positive public relations will be at the forefront of the discussion, including ways to coordinate logistics, activation of messages for “rumor control,” how to correct erroneous or misleading information, ways to mitigate negative publicity and how to effectively answer questions from the public and the press.

Public Awareness … Not Just For Regulated Pipelines AnymorePresented by Catreana McMullen, pipeline safety specialist, Chesapeake Energy

Chesapeake Energy is the second largest producer of natural gas in the United States and is a strong proponent for the increased use of natural gas as a source of energy to reduce our dependence of foreign oil. Chesapeake’s gathering pipeline subsidiary, Chesapeake Midstream, is fully committed to the implementation and effectiveness of its public awareness campaign program to promote the safety of our pipelines. After determining that more than 80 percent of its pipelines are not “regulated” by the Department of Transportation regulations and API RP 1162, Chesapeake Midstream piloted an enhancement program in 2011 to include programs for excavators and emergency officials in high-profile areas of non-reg-ulated pipelines. Oil and gas fathering operators will benefit from this session by evaluating their current public awareness programs and seeking new ways to provide outreach more effectively for excavators and emergency officials.

For more information on the conference go to www.CGAconference.com and for more information on the CGA go to www.CommonGroundAlliance.com


The oil sands in Western Canada continue to be the driv-ing force in new pipeline construction initiatives. Com-

panies like Syncrude Canada Ltd., Suncor Energy Inc. and Albian Sands Energy Inc., to name a few, are the big players in the region, while Enbridge tops the charts in terms of pipeline construction.

All this action in and around Fort McMurray, Alberta, and the strong demand for oil provide a stable market for pipeline contractors in Canada, says Kevin Waschuk, vice president of Waschuk Pipe Line Construction Ltd. and editorial board member with North American Oil & Gas Pipelines.

“Certainly, these large companies have been focusing on increasing their barrels per day,” Waschuk says. “The de-mand is there, so ultimately the product has to be shipped to the various markets.”

Waschuk says Enbridge has been the main transporter of oil in the region for a number of years, building out large diameter mainlines to ship product to refineries and even-tually to the market. Despite an unstable global economy, things look good for the oil pipeline construction industry in Canada.

“The market looks to be quite stable for oil pipeline con-struction here in 2012,” Waschuk says. “Enbridge is active now. You have to remember that most of this work starts in the north, so as there are muskeg conditions to deal with, frost is required, so winter construction takes precedence for the first and last quarters of 2012.”

Muskeg is a marshy soil found in arctic and sub-arctic regions, like that of Western Canada. Therefore, the unsta-ble terrain is better suited for winter construction, when the soil is harder.

Oil Pipelines in the NorthReporting the Latest Developments in Canadian Oil Pipelines

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However, soil conditions are not the only challenges pipeline contractors will face this year.

“The main challenges that we as contractors face are resources,” Waschuk says. “Attracting and securing peo-ple are vital. We are all dealing with an aging workforce, so training the up-and-coming youth is very important. Also at times, acquiring certain equipment can be a factor. It is also important to note that with the tougher, larger projects we have to work closer with our clients to secure contracts that are beneficial to both parties.”

Probably the biggest challenge for the oil industry, Waschuk says, is proving to the general public that oil is a necessary resource. While environmentalists serve their purpose in society, he says the media attention some of these groups get hinders the facts.

“Up here in Canada and in the West, we have one of the greatest natural resource pockets in Fort McMurray, Alber-ta, with the oil sands,” he says. “Certainly, this has been and will continue to be one of the main drivers for the oil industry. The product is there, the demand is there, so pipelines will be built to deliver the product to wherever markets dictate.”

Currently, there are a number of pipeline projects under construction or awaiting approval from the Canadian gov-ernment. What follows is an overview of those projects and their current progress:

Bakken Pipeline Project Location: Saskatchewan Stakeholder(s): EnbridgeOverview: In the effort to connect Canadian energy resources with the U.S. Midwest, this 124-km, 16-in. pipe-line is proposed to start by the second quarter of 2012 and be completed by the end of the year. The pipeline will connect to the Enbridge Pipelines Inc. (EPI) main-line and will serve as a continuous, long-term source of supply to Eastern Canadian and U.S. Midwest markets, thus maintaining the long-term competitiveness of re-fineries in those regions. In its application to the Cana-dian National Energy Board (NEB), Enbridge requested approval to build and operate a new pump station along with the pipeline to transport crude oil from the Bakken and the Three Forks Formations in Montana and North Dakota to refinery markets in North America. With a starting point in Steelman, Saskatchewan, the pipeline will be linked to EPI’s mainline in Cromer, Manitoba. The NEB approved the project Dec. 22, 2011. The board has also given Enbridge Bakken approval to acquire and operate Line EX-02, which is currently owned by Enbridge Pipelines (Westspur) Inc. With an expected in service date of early 2013, the capital cost for this project is estimated to reach approximately $180.1 million.

Line 9 Reversal Phase I Project Location: OntarioStakeholder(s): EnbridgeOverview: Currently under review by the NEB, Enbridge has applied to make additions and modifications required to allow the reversal of crude oil flow within a segment of Line 9, a 30-in. diameter crude oil pipeline from the Sarnia Terminal to the North Westover Station in southwestern Ontario. All proposed work would take place on existing Enbridge facilities and surface leases, with no planned ground disturbance along the pipeline right of way. The shift in flow direction from west to east would see the

pipeline revert back to the direction that was originally approved in 1975. The current westward flow has been in place since 1999. The NEB began holding public informa-tion sessions about the project in January.

Norealis Pipeline Project Location: Alberta Stakeholder(s): Enbridge, Husky Oil Operations Ltd.Overview: Phase 1 of this 112-km, 24-in. pipeline project is proposed to start by the fourth quarter of 2012, with a completion date in the first quarter of 2013. The Norealis Pipeline will transport blended bitumen (bitumen blended with a diluent such as condensate) from the Sunrise Energy facility to Enbridge Athabasca’s existing Cheecham Termi-nal. From there the Sunrise production will be transported on Enbridge’s Regional Oil Sands System. The pipeline and facilities will have capacity for other producers in the area as well, to meet increasing demand. The project received regulatory approval from the Alberta Energy Resources Conservation Board (ERCB) in April 2011.

Northern Gateway Pipeline Project Location: Alberta, British ColumbiaStakeholder(s): EnbridgeOverview: The Northern Gateway system would include two 1,177-km pipelines from Alberta to the British Colum-bian coastline, with associated storage tanks and terminals, at a cost of $5.5 billion. Crude oil could then be taken by ship to the Pacific Rim countries. The project is currently under review by the NEB joint review panel.

Wood Buffalo Pipeline Project Location: AlbertaStakeholder(s): Enbridge, SuncorOverview: This 95-km, 30-in. pipeline is currently under construction, from Enbridge’s Athabasca Terminal to the Cheecham Terminal and then connecting to the company’s existing pipeline that extends to its Edmonton Terminal. The project also includes construction of a pump station at the pipeline initiation point at the Athabasca Terminal and includes three 5,750-hp pump units, two new booster pumps and replacement of two other booster pumps with larger capacity units. There will also be a pump station at the pipeline mid-point, located in the Lynton area, which includes two 5,750-hp pump units. Completion is expected by April.

Woodland Pipeline Project Location: AlbertaStakeholder(s): Enbridge, Imperial Oil Ltd.Overview: This 137-km, 36-in. pipeline is currently under construction, from the Kearl oil sands to the Cheecham Terminal, which is about 70 km south of Fort McMurray. The project also includes a pump station in the Kearl sands region and two 300,000 barrel tanks and related facilities at the Cheecham Terminal. Initial pipeline capacity will be approximately 200,000 barrels per day. Completion is expected by April this year.

For more information about these projects, you can visit the NEB website at www.neb-one.gc.ca or the ERCB site at www.ercb.ca.

Bradley Kramer is associate editor of North American Oil & Gas Pipelines. Contact him at [email protected].

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CRC-Evans P625 Dual Torch Welding SystemThe CRC-Evans Pipeline International P625, the

latest version of its dual torch welding system, is in a class of its own. The machine weighs only 33 lbs, but can achieve an optional travel speed of 5 to 60 in. per minute and is designed perform in extreme temperatures ranging from minus-40 C to 60 C. The reduced size of the welding bug improves the overall welding cycle time and allows for more effi-cient use of two machines on smaller diameter pipe. Potential breakdowns of the welding station are no longer a concern because the P625 is designed with digital communication to reduce cable complexities. This machine has the ability to perform external root pass welding in addition to standard hot, fill and cap pass welding. Each weld is high quality, consistent and repeatable, thanks to digital welding technology. Users can perform 32 programmable welding passes per torch, and the machine offers full through-the-arc tracking, maximizing the weld quality in both vertical and horizontal applications. Perhaps the greatest advantage of the P625 is that all its features are part of a fully integrated digital system. Applications for PC, Notebook or PDA allow users to set and edit weld parameters (volts, amps, travel speed, oscillation, etc.) in the office and then wirelessly download them directly to the P625 in the field, where changes can also be made securely via CRC-Evans’ RFID access control. The P625 simply follows the individual’s instructions, giving the user complete control over the weld-ing process and complete assurance of job quality via a user-friendly spreadsheet interface. The high-speed embedded system processor ensures precise control of welding parameters, even at high welding speeds. Users can store a real-time log of machine data on every weld and carry it back to the office for quality control analysis and reporting. Human error is virtually taken out of the equation and it is rest-assured that every weld is on spec. For more information, visit www.crc-evans.com.

Hobart Bros. FabCO 750M Gas-Shielded Flux-Cored WireCaught on a wire? Hobart Bros.’ new FabCO 750M gas-shielded flux-cored wire can help. The wire was designed to provide low diffus-

ible hydrogen weld deposits (3.5 ml per 100 g of weldment) on high-strength pipeline applications and minimize the risk of under-bead cracking. It is especially well-suited for welding API 5L Grade X100 pipe or as an overmatch on API 5L Grade X80 pipe. Other applications for FabCO 750M wire include high-strength, low-alloy steels; ABS EQ 56, 63 and 70 steel; and jack-up rig construction. FabCO 750M

wire features low spatter levels and an easy-to-remove slag to reduce inter-pass and post-weld cleanup, and lessen instances of inclusions. The wire also provides excellent arc character-istics, allowing operators to produce smooth weld beads with uniform fusion. FabCO 750M wire offers high-impact strengths at tempera-tures as low as minus-60 F (minus-50 C). It op-erates with a shielding gas mixture of 75 to 80 percent argon and a balance of carbon dioxide and provides a tensile strength of 121 ksi (us-ing a 75/25 shielding gas mixture). The wire can be used for welding in all positions. Hobart Bros. offers FabCO 750M wire in 0.045-in. diameters. The company is a leading manufacturer of weld-ing filler metals and based in Troy, Ohio. Its products are marketed under the brand names Hobart, Tri-Mark, McKay and Corex. Hobart Bros. is a wholly owned subsidiary of Illinois Tool Works Inc., based in Glenview, Ill. For more infor-mation, visit www.hobartbrothers.com.


Lincoln Electric Activ8 Semiautomatic Wire FeederDesigned for use in shipbuilding, offshore, construction or pipe welding operations, the Activ8 portable wire feeder from Lincoln

Electric offers a modular design that is small enough to fit through ship manways and light enough to carry around the jobsite. The portable wire feeder is capable of feeding self-shielded FCAW or FCAW-G and GMAW (MIG) gas-shielded wires at 50 to 800 in. per minute (1.3 to 20.3 m per minute). It will handle GMAW wires 0.023 to 0.052 in. (0.6 to 1.3 mm) in diameter and FCAW wires of 0.035 to 5/64 in. (0.9 to 2 mm) in diameter. The Activ8 is rated at 330 amps at 60 percent duty cycle and weighs in at 27 lbs (12.2 kg). Key features of the Activ8 system include:

• Designed specifically for 8 in. (200 mm) spools• Compatible with any DC CV and/or CC power

source• Simple controls include front WFS knob and in-

ternal booted Cold Feed and Gas Purges, Trig-ger Interlock and CV/CC switches

• Across-the-arc operation (voltage sensing) uses a sense lead and contactor to enable weld current

• Standard shielding gas apparatus can be used for FCAW-G and GMAW processes

• Tough plastic case, molded from high-impact, flame-retardant material, is durable and light-weight enough to withstand repeated drop testing

At the heart of the Activ8 wire feeder is the MAX-TRAC Drive System, which features:

• Dual gear-driven drive system to ensure positive feeding performance

• Patented wire drive with tool-less drive roller and wire guide changes for quick spool replacement

• Tachometer-controlled motor to power drive rolls for smooth, steady feeding without wire slippageFor more information, visit www.lincolnelectric.com.

Miller Big Blue 700 Duo Pro Welding GeneratorMiller Electric Mfg. Co. introduces the brand new Big Blue 700 Duo Pro, a diesel engine-driven welder and AC generator that of-

fers powerful, independent multi-arc welding in transmission pipeline, process pipe, construction and MRO welding applications. The machine offers two independent welding arcs up to 400 amps (no interaction between the arcs), and the ability to parallel both indepen-dent welding outputs to create an extremely powerful 800 amps of welding power for running large electrodes, stud welding and carbon arc gouging (up to 3/8-in. carbons). Offering full multi-process capabili-ties (stick, MIG, flux-cored, TIG, carbon arc gouging), the Big Blue 700 Duo Pro also offers two independent generator outputs. One 5,500-watt peak/4,000-watt continuous single-phase generator is fully indepen-dent of weld output and offers peak performance even when welding at 700 amps (no interaction between arc and generator). The second generator (27,000 watts peak/20,000 watts continuous) provides more robust power for high power needs on site. The benefit of a multi-oper-ator system like the Big Blue 700 Duo Pro exists in its ability to provide two high-quality welding arcs in one engine-driven unit. This allows you to get the work of two machines done with one (two operators use one machine). An example would be in transmission pipeline welding applications where two welders work simultaneously down opposite sides of a single pipe. In addition to the equipment cost-savings of one machine compared to two, the Big Blue 700 Duo Pro uses an estimated 58 percent less fuel than two single-operator units with comparable en-gine power. It’s also easier to transport, produces less noise and fewer emissions compared to two separate machines. Powered by Deutz’s D2011 L04 four-cylinder heavy-duty, low-speed diesel engine, the Big Blue 700 Duo Pro is designed to operate for 10,000 hours before its first

basic overhaul. The machine is EPA Tier 4 Interim compliant, runs at a low 1,800 rpm, and is considerably quieter than most com-parable machines — rated at just 75 dB at 23 ft under full load. The machine is also 11 percent smaller and 15 percent lighter than Miller’s previous dual operator system in this size class. Visit www.millerwelds.com for more information.


Serimax Saturnax 09The various different pipeline contract types are becoming more and more technically demanding and call for welding techniques

that are more and more precise. To meet these new challenges, Serimax has decided to launch a new welding trolley with a vast range of applications: The Saturnax 09. The thinking behind this new unit is extreme versatility, with the ability to handle multiple welding processes, so as to offer contractors a unique tool with a huge range of uses while being compatible with all kinds of pipeline projects. The Saturnax 09 accommodates a range of processes, from traditional dual GMAW, dual PGMAW and CMT. This new trolley is capable of welding on any type of edge (V, J or K) in any position (1G, 2G, 5G and 6G), on Serimax Classic bands. This new trol-ley also meets customers’ expectations when it comes to cut-back reduction. The cut-back is the distance over which the end of the pipe is bare, with the coating removed. The more the cut-back is reduced, the less pipe protection materials need to be installed on the production line, and the fewer materials need to be transported to the laying site. The Saturnax 09 reduces this cut-back distance by about 70 mm on a joint to be welded in the case of a concrete element at 90 degrees and with a concrete element at 45 degrees can even reduce it to 100 mm. The Saturnax 09 is an innovation in the HSE sector, making use of a native fume and smoke aspiration system, and sets new standards in the quality of ergonomic in use (versatile two-hand control of the latch-roller, torch alignment, etc.). Additionally, the new welder has been reduced in weight and allows for easier maintenance than previous models. For a bug and band welding system, the weight of the trolley is an essential consideration. On average, a trolley is handled a hundred times per work location. This makes it essential that the new unit is capable of taking on whatever system the welders use. The new trolley is also retro-compatible for use by welders who have already worked on Saturnax III, V or 07. Visit www.serimax.com for more information.

Thermal Arc Fabricator 252i “3-in-1” MIG-Stick-TIG Welder Need a little variety in your welding? Thermal Arc, a Thermadyne brand, has launched the Fabricator 252i “3-in-1” MIG-Stick-TIG

welding system. Weighing 66 lbs. and with an output range of 5 to 300 amps (250 amps at 40 percent duty cycle), the Fabricator 252i is the second in a new category of multi-process, fully integrated, portable welders. With an MSRP of $2,509 for the base package, the machine provides three welding processes for the price of competi-tive MIG-only units. The Fabricator 252i enables users to choose the best process for the application at hand. For example, its MIG and gas-shielded flux-cored outputs provide maximum productivity in the shop. The stick and self-shielded flux-cored processes work better in windy and outdoor conditions, as well as on rusty or dirty metal. And the DC TIG process enables users to weld stainless, copper, nick-el, bronze or brass alloys or on applications requiring precise con-trol over heat input and weld bead placement. Using 208 to 230 volts primary power, the Fabricator 252i provides the following outputs:

• MIG/Flux-cored: 5 to 300 amps/14 to 30 volts (250A/26.5V at 40 percent duty cycle). It can run solid wires from .023- to .045-in. diameter, flux-cored wires from 0.030- to 0.045-in. and aluminum wires from 0.030- to 3/64-in. The unit accepts 4-, 8- and 12-in. diam-eter wire spools.

• Stick (DC only): Up to 300 amps (230A/29.2V at 40 percent duty cycle), suitable for running Stick electrodes up to ¼-in. diameter.

• TIG (DC only): 5 to 300 amps (250A/20V at 40 percent duty cycle), suitable for running all common diameter tungsten electrodes.

The Fabricator 252i features power factor correction (PFC), which lowers the unit’s primary current draw and enables it to provide full output on a 50-amp circuit. The unit comes with a TWECO Spray

Master 250-amp MIG gun, TWECO WeldSkill 200-amp Stick electrode holder and Victor EDGE regulator. For more information, visit www.thermalarc.com.



North American Oil & Gas Pipelines Calendar

February

21-25PLCA Annual ConventionPark Hyatt Aviara Carlsbad, Calif.Web: www.plca.org

29-March 4APCA Annual ConventionThe CloisterSea Island, Ga. Web: www.americanpipeline.org

March

6-8API Conference & ExpoMarina Bay Sands HotelSingaporeWeb: www.apiexpo.org

6-8CGA Excavation Safety Conference and ExpoRio HotelLas VegasWeb: www.cgaconference.com

9-14PCCA Annual ConventionHyatt Regency Hill Country Resort & SpaSan AntonioWeb: www.pccaweb.org

11-15NASTT’s 2012 No-Dig ShowNorth American Society for Trenchless Technology (NASTT)Gaylord Opryland Hotel & Convention CenterNashville, Tenn.Web: www.nodigshow.com

12-16NUCA Annual ConventionRenaissance Worthington HotelFort Worth, Texas Web: www.nuca.com

13-17AGC of American Annual ConventionHilton Hawaii Village Beach Resort & SpaHonoluluWeb: www.agc.org

April

10-11ShaleComm 2012Westin Convention CenterPittsburghWeb: www.ShaleComms.com

11-13 INGAA Foundation Spring MeetingMarriott San Antonio Hill Country Resort & SpaSan AntonioWeb: www.ingaa.org

16-18DCA Annual Safety CongressPlanet HollywoodLas VegasWeb: www.dca-online.org

17-19API Pipeline ConferenceAmerican Petroleum InstituteWeb: www.api.org

30-May 3OTC2012 Offshore Technology ConferenceReliant ParkHoustonWeb: www.otcnet.org

May

15-17Appalachian Underground Corrosion Short Course (AUCSC 2012) West Virginia UniversityMorgantown, W.Va. Web: www.aucsc.com

June

3-7PLCA Canada Annual ConventionFairmont ChateauWhistler, British ColumbiaWeb: www.pipeline.ca

Submit events to [email protected] with “Events Calendar” in the subject.

The Events Pipeline Conferences, Meetings & Trade Shows

Advertiser Website Page #

Benjamin Media Resource Center ............ www.benjaminmedia.com/book-store .......37

Darby Equipment ...................................... www.darbyequip.com ..................................7

E-Z Line Support Company Inc ................. www.ezline.com ...........................................5

Fecon Inc. .................................................. www.fecon.com .........................................21

Finn Corporation ....................................... www.FINNcorp.com ..................................11

Horizontal Technology Inc. ........................ www.horizontaltech.com .............................3

John Deere ................................................ www.JohnDeere.com/YoureOn .................48

McLaughlin ................................................ www.mightymole.com ...............................13

Mesa .......................................................... www.mesaproducts.com ...........................46

Michels Corporation .................................. www.michels.us .........................................14

Advertiser Website Page #

NACE International .................................... www.Nace.org/education ..........................23

NASTT’s 2012 No-Dig Show ..................... wwwnodigshow.com .................................40

Opportunities in Utility

Construction Conference .......................... www.trenchlessonline.com ........................39

Polyguard Products ................................... www.polyguardproducts.com ...................24

Rig Source ................................................. www.rigsourceinc.com ................................2

Superior Tire & Rubber Corp..................... www.track-pads.com ...................................9

The HDD Co. ............................................. www.hddcompany.com .............................19

Vacuworx International .............................. www.vacuworx.com ...................................17

Wounded Warrior Project .......................... www.woundedwarriorproject.org ...............47

Advertisers Index


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