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P i p e l i n e & G a s J o u r n a l

J u l y 2 0 1 8

V o l u m e N o . 2 4 5 N u m b e r 7

LOOKING AHEAD. We plan for the future. More than one-third of ROSEN employees employ ees work in research and development, creating innovative products needed by the industry. An investment investment we are proud of.

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TABLE OF

Contents Since 1859, the worldwide authority in pipeline operations.

July 2018 • Vol. 245 • No. 7

16 | Memphis Utility Makes Big Inroads in 30-Year Replacement Plan 18 | What a Gas Measurement Technician Technician Needs to Know for Success 22 | Nigeria Makes Progress on Delayed Gas Pipeline Project

87 | Egypt: The Next Natural Gas Hotspot 88 | Closer Look at Flammability, Inerting of Complex Hydrocarbon Mixtures Tom Martin 112 | A Conversation with Kinder Morgan’s Tom

24 | Innovation, Technology Reshape North Dakota’s Bakken Shale 28 | New Day for Pipeline Tolls 30 | Designing of Skin Effect Current Traced Cross-Country Pipelines 34 | Mobile Technology Takes Pipeline Data to the Cloud 36 | Northeast Looking at Record Natural Gas Pipeline Buildout in 2018 38 | Getting into the Pig Launcher Groove 39 | Real-Time Views of Measurement for Performing Data Analytics

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CAPABILITIES CAP ABILITIES GUIDE

The P&GJ Capabilities Guide is an annual special section that serves as a marketplace for suppliers of products and services to the pipeline and gas utility industry. Display advertisers in this section receive complimentary matching space to present capabilities and key benefits in greater depth through advertorials, case studies or other brand promotion.

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DEPARTMENTS 02 I Guest Commentary 04 I Global News 08 I Government 10 I Projects 14 I Legal Perspectives 92 I Meetings 93 I What’s New 94 I Tech Notes 96 I Business 98 I Business Card Directory 110 I Sale Sales s Reps 110 11 0 I Advertiser’s Index

ON THE COVER About 180 miles of 42-inch greenfield pipe is being installed in Pennsylvania as part of Williams’ $3 billion Atlantic Sunrise project, which will add 1.7 MMcfd of capacity to the Transco system. Mechanical completion is expected later this summer.

NEXT MONTH August’s issue of P&GJ will will put the spotlight on Mexico’s expanding energy infrastructure, such as this natural gas pipeline running from Texas into the Nuevo Nuev o Leon Leon state. state.

www.pgjonline.com www.pgjonline.com

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GUEST COMMENTARY

P.O. Box 2608 Houston, TX 77252-2608, 7 7252-2608, USA Phone: (713) 529-4301 www.pgjonline.com

Jeff Lee, Kronas Management

Why Canadians Should do the World a Favor and Build More Pipelines The Canadian federal government just lent its full force behind Kinder Morgan’s TransMountain pipeline by taking a stake in the project, promising to push through construction despite fierce provincial resistance from British Columbia. Activists and politicians in BC did not waste time ti me condemning the move. To be sure, pipeline projects put a disproportionate burden on certain First Nations and municipalities. But Jeff Lee from a national interest, economic, humanitarian, and even environmental standpoint, there is a strong case for Canadian pipelines. This includes establishing a natural-gas export corridor from Prince George to Prince Rupert, completing the Trans Mountain loop and Keystone expansion, and freezing future pipeline development. The world will t hank Canada for it. Two billion people from mostly developing countries will be added to the global population in the coming decades. Access to cheap and reliable energy sources will raise their quality of life. To demand nothing but clean renewable energy is impractical and disingenuous, even cruel. Consider also the global environmental footprint. Canada has among the highest environmental standards for oil and gas development. When a big consumer like China buys from Canada, it takes demand away from dirtier coal and reduces the net car bon footprint. A hypothetical 800-kilometer, 800-kilometer, multiple-pipeline corridor would require about 400 square kilometers of restorable land. Contrast that to the nearly 9,000 square kilometers (22 times) of land consumed in a single forestfire season in British Columbia last year. The world is rapidly moving toward cleaner and renewable-energy sources due to falling costs and advancements advancements in solar, battery technologies and demographic trends. Canada should bank the money while it can. In 20 years, there may no longer be talk about new fossil-fuel investments. Currently, constrained export pipelines are causing Canadians to subsidize American shale producers by selling at a consistent discount. Canadian producers have had to load more oil on railcars, which are less safe and more energy intensive. “Turning off” oil and gas will have huge repercussions. Job losses and reduced social benefits will hurt the lives of millions of lower-income Canadians. Moreover, by developing policies unpredictably and discrediting decisions by legitimate institutions such as the National Energy Board, the governments risk destroying Canada’s credibility to investors in all industries and undermining rules-based democracy in favor of populism. In the age of protectionism, Canada Canada should secure secure all its revenue streams. streams. Natural resources resources must be strategically managed. Good fortune has been squandered for too long and Canada needs to build a Norwegian-style sovereign wealth fund. This fund can be used for research, prize programs for innovations, sustainable social welfare and job-training programs to prepare Canadians for t he future. There is nothing hypocritical about denying resource revenues from illiberal countries. Canada can accelerate meaningful reforms while pursuing worthy causes in many places. For too long Canada has punched below its weight on international affairs. By supplying more energy, Canada can support its peaceful projection of power, forge closer ties with its trading partners and reduce everyone’s reliance on corrupt regimes. To paraphrase a former Saudi oil minister, “The Stone Age did not end because of a lack of stones.” The demise of fossil fuel will come from better technologies and economics, and it will be a gradual process. The notion that stopping resource development development now would force us into renewable energies is a myth. Many people have been lured into ideological purity, purity, false expectations of a quick solution, or worse, activism for activism’ activism’ss sake. Discussions should instead be directed at the responsible use of oil revenues and ways t o enhance Canadians’ quality of life. Canadians should be proud to provide the world with a reliable and cleaner source of energy. By the same token, Canadians should be embarrassed that, after decades of oil and gas production, no lasting legacy is visible from this one-time gain. Opportunities were squandered, but aren’t lost forever. Now is the time to step up and do us all a favor, Canada. 2

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Pipeline & Gas Journal July 2018 • •

EDITORIAL Publisher:

Brian Nessen [email protected]

Editor

Joe Hollier [email protected]

Executive Editor

Jeff Awalt Jeff[email protected]

Managing Editor

Michael Reed [email protected]

Contributing Editors

Stephen Barlas Richard Nemec Nicholas Newman Mauro Nogarin

Consultant

Oliver C. Klinger III

MAGAZINE PRODUCTION Vice Presiden Presidentt Producti on

(713) 525-4604 Sheryl Stone [email protected]

Art Director

Sheri Biscardi [email protected]

Advertising Manager

Cheryl Willis [email protected]

EVENTS Convention Director

Karen Francis [email protected]

ADVERTISING SALES For complete list of sales representatives please refer to page . CIRCULATION Customer Service

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SUBSCRIPTIONS Pipeline & Gas Journal (USPS 040-970) (ISSN 32-0188) is published

monthly by Gulf Publishing Company, 2 Greenway Plaza, Suite 1020, Houston, TX 77046. Circulation Department: PO Box 2608, Houston, Houston, TX 772522608. © Copyright 2018 by Gulf Publishing Holdings LLC. All rights reserved. No part of this publication may be transmitted or reproduced in any form or by any means, electronic or mechanical, including photocopy, recording or any information storage and retrieval system, without permission in writing from the Publisher. Subscription rates are: one year $199, two years $340, 3 years $440. One year airmail is $175. Current year single issue copies (pre-paid only): $25 plus postage. Back issues one year old or more: $25 plus postage. November Annual 500 Report $50 plus postage. Cumulative editions of this publication are available in microfilm from University Microfilms Inc., N. Zeeb Rd, Ann Arbor, Arbor, MI 48106. Ph: (313) 761-4700. Periodical class postage paid in Houston, TX and additional mailing offices. Postmaster and address changes to: Pipeline & Gas Journal, PO Box 2608, Houston, TX 77252-2608. REPRINTS & E-PRINT PRODUCTS Foster Printing at Mossberg & Co. Jill Kaletha [email protected] 574-289-9253 x149 or 800-428-3340 x149

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GLOBAL NEWS

Report: Produced Water Creates Growing Risk to Permian Growth Permian tight oil cost curve comparison: two water scenarios

Water cuts – the ratio of water vs. liquids volumes produced – typically increase as oilfields mature. Pipeline infrastructure can reduce costs in formations like Wolfcamp, which starts at a high base of about 70-80%. Graphic: Wood Mackenzie

As operators continue ramping up Permian Basin activity and takeaway demand, operational water challenges are emerging as a growing material risk to future upstream profitability and production, productio n, according to a new ne w Wood Wood Mackenzie study. Ryan Duman, principal analyst with Wood Mackenzie’s Lower 48 upstream team, said the firm expects more than 2 MMbpd of oil supply growth in the next five years. “While attainable, the list of operational risks grows too, and the least appreciated of these is produce prod uced d water water,” ,” Duman Duman said. said. “The com combina binatio tion n of rising rising volu volumes mes and and higher higher disp disposa osall costs costs threaten to shift cost curves and pose a growing risk to oil production growth in the Permian.” The study, Permian produced water: slowly extinguishing a roaring basin?, modeled various scenarios of rising water cuts and growing water management costs. In its “aggressive” future cost scenario, breakeven costs in the Midland and Delaware sub-plays could increase by $3-$6 per barrel, potentially curbing the growth of future Permian oil supply by 400,000 bpd by 2025. “Water risks to date have largely been described as a cost issue, but as projects continue to build scale, the risks become more serious,” Duman said. Unlike some of the other subsurface constraints and risks facing the Permian, there are ways operators can mitigate risks from produced water. “One of the best opportunities for operators to reduce water costs is by investing in pipeline infrastructure, limiting the amount of trucking and collaborating with offset operators,” Duman said. �

Devon Energy Sells EnLink Midstream Stakes for $3.1 Billion

Solaris Water Midstream Starts Pecos Star Operations

Devon Energy agreed to sell its ownSolaris Water Midstream began operaership interests in EnLink Midstream tions on the first phase of its 300-mile Pecos Partners and Enlink Midstream to an affil- Star water system, which is designed to iate of fund manager Global Infrastructure serve oil and gas producers in the Delaware Basin of West Texas and New Mexico. Partners (GIP) for $3.1 billion. Phase One of Solaris Water’s Pecos Star As part of this transaction, Devon will extend its fixed-fee gathering and processing System comprises 50 miles of 12- and 16-inch produced-w d-wate aterr pip pipeli elines, nes, mul multip tiple le dis disposa posallcontracts with respect to the Bridgeport and produce Cana plants with EnLink through 2029. The well connections, the ability to supply recycled company’s minimum volume commitments for water and freshwater wells and ponds. The build-out of additional phases is underthese agreements will expire at the end of o f 2018. EnLink said it will continue to maintain a way, with continuous construction expected over strong commercial relationship with Devon the course of the coming year. Upon complethrough long-term contracts as the compa- tion, the Pecos Star System will include an integrated network of more than 300 nies work alongside each other to maxi- extensive integrated mize returns in the STACK, redevelop the miles of high-capacity gathering and distribution pipelin lines es ran rangin ging g from from 12 to 16 inc inches hes in dia diammBarnett Shale and team up on new potential pipe opportunities, such as crude gathering in the eter, dozens of disposal wells, storage ponds, aboveground storage and recycling facilities. Delaware Basin. 4

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EPIC Secures Strategic Partnerships for Crude Oil Pipeline Apache Corporation and Noble Energy committed to anchor the EPIC Crude Oil Pipeline, which will run side-by-side with the EPIC NGL Pipeline for 730 miles from southeastern New Mexico to Corpus Christi, Texas. The pipeline will have an initial total capacity of 590,000 bpd, including 440,000 bpd from the Permian Basin and 150,000 bpd from the Eagle Ford shale. Apache and Noble Energy have secured 75,000 bpd and 100 bpd of firm capacity, respectively. As part of their strategic partnerships, Apache will have an option to acquire a 15% interest in the pipeline, with Noble having an option to acquire a 30% interest, as well as a 15% interest in the EPIC NGL Pipeline. All options expire in the first quarter of 2019. The EPIC Crude Oil Pipeline will extend from Orla, Texas, to the Port of Corpus Christi, Texas. The project includes terminals in Orla, Pecos, Saragosa, Crane, Wink, Midland, Helena and Gardendale, with Port of Corpus Christi connectivity and export access. Right-of-way Right-of-way is 100% secured for the first two phases of the system, and construction is expected to commence in the fourth quarter of 2018. The pipeline expected to be in service in the second half of 2019.

Nord Stream 2 Gains Swedish Approval Russia’s Gazprom’s proposed Nord Stream 2 natural gas pipeline from Russia to Germany received construction approval from Sweden and Russia, leaving only Denmark as the sole nation remaining yet to decide on the project. Nord Stream 2 has already obtained permits for construction and operation of the pipeline system in Germany and Finland, and Gazprom has vowed that a rejection by Denmark would not stop it from completing the 1,230-km (764-mile) pipeline, but could delay the project. The permit from Sweden’s Ministry of Enterprise and Innovation covers an about 510-km route section in the Swedish Exclusive Economic Zone. The controversial Gazprom project has been opposed by the United States on the basis of “European energy security” and by European nations concerned over growing reliance on Russian gas and the financial impact on Ukraine, which will lose income as natural gas deliveries shift to Nord Stream 2 and bypass its pipelines. Poland’s prime minister has been increasingly vocal about the project, calling it a “new hybrid weapon” that Moscow will use it to undermine NATO and the European Union.

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GLOBAL NEWS

Trans Mountain Pipeline, Expansion Selling for C$4.5 Billion

A tanker prepares for departure from the Westridge Marine Terminal with oil from the Trans Mountain Pipeline, a scene that will become more common after the system system expansion. Photo: Kinder Morgan Canada

Kinder Morgan said that Kinder Morgan Canada Limited agreed to the purchase of the Trans Mountain Pipeline system and the expansion project (TMEP) by the Canada government for C$4.5 billion (US$3.46 billion). As part of the agreement, the government will fund the resumption of TMEP planning and construction work by guaranteeing TMEP’s advances under a separate federal recourse credit facility until the transaction closes. “The outcome reached represents the best opportunity to complete TMEP and thereby realize the great economic benefits promised by that project,” said KMI CEO and KML Chairman and CEO Steve Kean. Earlier, Kinder Morgan halted essential spending o n the project and said it would cancel ca ncel it altogether altogeth er if the national nati onal and provincial provin cial governments could not guarantee it. Canada has the world’s third-largest oil reserves, but 99% of its exports go to refiners in the U.S., where Canadian oil sells at a discount. �

First LNG Shipment Leaves Cameroon Plant Built on Old Tanker

SoCalGas Warns Supply Could Fall Short

Southern California Gas (SoCalGas) has Golar LNG has started commercial oper- cautioned that pipeline outages and restrications at its pioneering floating liquefied tions on the Aliso Canyon gas storage natural gas (FLNG) production platform facility could reduce its ability to deliver in Cameroon, $70 million under budget, natural gas this year to a level even lower Reuters reported. than California state regulators and others The first of its kind, the Hilli Episeyo have predicted. vessel was converted from an aging LNG Regulators, power companies and grid tanker for $1.2 billion. The successful start- operators issued a technical report in May up removes uncertainty about the risks warning of a “moderate threat” to gas and associated with squeezing a liquefaction electric reliability this summer and a “more plant typically spanning hundreds of acres serious threat” next winter. on land into a single, 1970s-built ship with “We remain concerned that some of four liquefaction units bolted onto its sides. the assumptions made in the techniIt produced the first LNG on March 12 but only exported its first cargo in May, cal assessment are overly optimistic,” to China, after technical issues delayed SoCalGas spokesman Chris Gilbride a ramp-up in production. After continu- said. The SoCalGas system has been operously producing LNG for 16 more days, ating at less than full capacity because Golar’s clients have contractually accepted the facility, marking its commercial start, of the pipeline outages and restrictions Golar said in a statement. Golar is in talks on the use of Aliso Canyon, the utility’s gest st sto rag e fie ld, whi ch suf suffer fer ed a to develop similar projects in Senegal- big ge devastating leak between October 2015 Mauritania with BP and with Ophir Energy in Equatorial Guinea. and February 2016. 6

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Rover Pipeline’s Full Mainline B Goes into Full Service Energy Transfer Partners’ Rover Pipeline received approval from the Federal Energy Regulatory Commission (FERC) to begin service of the Supply Connector B and full Mainline B pipeline segments. Service to the Market Zone north segment of the pipeline, with deliveries into the Union Gas Dawn Storage Hub in Ontario, Canada, will begin by way of the Vector Pipeline Connection in Michigan. This latest approval allows for 100% of Rover’s mainline capacity, 3.25 Bcf/d of natural gas, to be placed into service. The FERC decision, however, did not allow gas to flow on two key laterals – the Burgettstown and the Majorsville – connecting to supply areas. Rover transports natural gas from the Marcellus and Utica Shale production areas to markets across the United States, as well as into the Union Gas Dawn Storage Hub.

GITA, Pipeline & Gas Journal Launch Technology Conference The Geospatial Information and Technology Association (GITA) and Pipe Pipeline line & Gas Journ Jo urnal al have agreed to produce the annual Pipeline Technology Forum, including the 27th GITA GIT A Oil and Gas Pipeline Conference. The Pipeline Technology Forum will be held Oct. 16-17 in Houston and replace a former GITA annual event known as Pipeline Week, according to GITA President Mark Limbruner. “The GITA board and I are extremely happy to have engaged with Gulf Energy Information to produce our 27th annual pipeline event. Our members and attendees should look forward to a refreshed and exciting conference,” Limbruner said. “Gulf’s ability to co-brand our event with the leading trade jour Pipeline line & Gas Jou Journa rnal, l, nal in the market, Pipe and its data for the pipeline industry, make it an ideal partner for GITA and for a vibrant and growing industry segment. The combination will also significantly increase the educational value of our annual conference.” More than 100 exhibitors and over 500 attendees are expected at the event, which will include general sessions and two tracks of technical presentations on the use of geospatial technologies, pipeline software and other applied technologies for the pipeline industry. GITA also will hold its board and association meetings during the event. “We are thrilled to be working with GITA GIT A to put on the annual conference and to to further learning and best practices for geospatial and pipeline technology professionals,” said Brian Nessen, group publisher for Pipeline & Gas Journal and Underground Construction. P&GJ

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GOVERNMENT Stephen Barlas, Contributing Editor, Washington, D.C.

Pipeline MLPs Fighting FERC Tax Moves Pipeline master limited partnerships (MLPs) want the Federal Energy Regulatory Commission (FERC) to reverse a March 2018 revised policy statement (RPS) that has dramatically hurt their financial conditions. The elimination of an MLP tax allowance would be exacerbated by a second March FERC proposal, which would significantly and negatively affect the rates they charge shippers. It allows pipelines to voluntarily file rate reductions to reflect the decrease in their federal corporate income tax, thanks to the Tax Cuts and Jobs Act (TCJA) signed by President Trump last December, or explain why no action is needed or take no action other than filing the informational filing. It is the RPS which is creating ha voc with the financial health of MLPs. Dominion Energy, Inc. has lost nearly $7 billion of market capitalization between March 15 and early May 2018 while Dominion Energy Midstream Partners, LP, owner of several interstate natural gas pipelines, lost approximately $730 million of market capitalization, or nearly 43 percent, during the same period, according to the company. In its first quarter 2018 financial statement, Enbridge, Inc., a Canadian com pany which owns U.S. pipelines such as Spectra Energy, said, “Many MLPs, including Spectra Energy Partners LP (SEP) and Enbridge Energy Partners, L.P. (EEP) both of which Enbridge sponsors and retains an equity interest in, have responded to the FERC announcement regarding tax allowance, both directly and through industry associations, objecting to the change in FERC policy and requesting a re-hearing.” Shippers, the Natural Gas Supply Association and others are pushing the FERC to act, because they believe the TCJA and the RPS have made the currently effective income tax allowance set forth in a pipeline’s cost of service service overstated. overstated. The pipelines pipelines argue argue that, even if current rates are higher than they would be, the shippers agreed to those rates and the resulting contracts should be sacrosanct unless a shipper can cite a “public interest” argument for revising rates mid-contract. “Absent extraordinary circumstances – which do not exist here – shippers cannot now seek to revise their contractually-binding arrangements, relied upon by natural gas pipelines pipel ines to suppo support rt impo important rtant infra infrastruc structure ture development, simply because a foreseeable change in the corporate income tax rate has now come to fruition,” wrote Matthew Eggerding, senior counsel, Midstream EQT Midstream Partners, LP, LP, in comments submitted to the FERC in May. “In the event they 8

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secondary gas supplies in an emergency – that is, buying gas from local distribution companies when a severe cold snap hits. The generators rarely enter into firm contracts with pipelines to guarantee supply. Comments submitted to the FERC by the California Independent System Operator Corp.; ISO New England, Inc. (ISO-NE); Midcontinent Independent System Operator, Inc.; New York Independent System Operator, Inc.; and Southwest Power Pool, Inc. stated, “…the record in this proceeding does not support any universal resilience standard or tariff changes requirements. The Commission should not impose on other RTOs/ISOs the specific actions and deadlines PJM requests, many of which are based on reforms PJM is pursuing to address issues specific to its region.” Not only have have other other RTOs/IS RTOs/ISOs Os ganged ganged up on PJM, but so have PJM’s industrial customcus tomers. Under the banner of the PJM Consumer Representatives, Representat ives, they include groups such as the American Forest and Paper Association, Association, American Iron and Steel Institute, Delaware Public Service Commission, Industrial Energy Users-Ohio and many others. They argue that PJM was using the FERC effort to improve power system “resilience” to force the agency to adopt changes to transmission and infrastructure planning, operation rules, and market rules. “Absent a common understanding and uniform definition, ensuring resilience is neither measurable nor auditable,” they argued. “Consequently, calibrating any such investment to ensure that consumers are not saddled with unnecessary costs, under the guise of ‘resilience,’ Substantial Opposition to PJM presents a significant challenge that must be Push for Higher Pipeline Rates addressed to ensure that rate results comport PJM Interconnection, the largest region- with the Federal Power Act.” al transmission organization (RTO) in the The Edison Electric Institute, which repU.S., is taking a beating from interstate pipe- resents the electric generation industry, gave lines, other RTOs and Independent System no support to PJM’s request, either. Instead, Operators (ISOs) – and even its customers it said steps FERC has already made to – becaus becausee of PJM’s proposal proposal for the Fede Federal ral enhance the resilience of the bulk-power sysEnergy Regulatory Commission (FERC) to tem should be considered, such as its recent require that RTOs and ISOs submit filings for conferences on electric-gas coordination and pipeline pipel ine rate adjust adjustment mentss in the name of assur assur-- efforts on price formation and transparency. ing electric grid “resilience.” The backlash New England England has been the reg region ion that has relates to PJM’s request for near-term help arguably been most affected by extreme cold after FERC invited industry input on solutions weather events as its electric generators had to the vulnerability of gas-dependent electric trouble getting U.S. gas last winter and had generators to extreme weather events. to rely on foreign LNG, in some instances. In Electric generators in the Midwest, where February, Boston received LNG imports from the electric power system is administered the $27 billion Yamal Peninsula project, a mas by PJM, and the th e Northeast Northeas t are increasingly sive new LNG complex in northern Siberia. dependent on natural gas as coal- and nucleAn analysis by ISO-NE found that energy ar-fired power stations are retired. Current shortfalls due to inadequate fuel supply supplies of natural gas to those areas, served would occur in almost every fuel-mix sce by PJM and ISO-New England, are to s ome nario in winter 2024-25, requiring frequent extent inadequate and further complicated use of emergency actions to fully meet by the fact that generators mostly rely on demand or protect the grid. P&GJ believe that a pipel believe pipeline ine has faile failed d to make a contractually-required adjustment, shippers are free to avail themselves of the Natural Gas Act’ss Section 5 complaint procedures.” Act’ Dominion argues that some shippers did negotiate contract provisions to account for a potential tax rate reduction nearly a year ahead of the TCJA as they had similarly done years ago in anticipation of the Tax Reform Act of 1986. “Given this history, shippers’ pleas for contract abrogation ring hollow hollow,” ,” wrote Margaret H. Peters, Managing General Counsel, Dominion Energy Services. The RPS piece of the proposed rule is clearly the bigger of the two irritants. The Interstate Natural Gas Association of America said removing the MLP income tax allowance issues from the proposed rule will reduce the uncertainty associated with the proposed rule and help allow pipelines and their customers to focus on the potential rate reductions resulting from the reduction of the corporate income tax rate in the TCJA. The proposed rule provides interstate natural gas pipeline companies four options to consider and address the reduced costs attributable to the TCJA and the Revised Policy Statement: 1) Submit a limited NGA Section 4 filing to reduce its rates by the percentage reduction in its cost of service resulting from the [TCJA] and the Revised Policy Statement, as calculated in the FERC Form No. 501-G; 2) Commit to file either a prepackaged uncontested settlement or, if that is not possible, a general NGA section 4 rate case by December 31, 2018; 3) File a statement explaining why an adjustment to rates is not needed; or, 4) Take no action.

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PROJECTS

Targa to Expand Grand Prix NGL Pipeline, Delaware Basin Capacity

Coastal GasLink Pipeline Construction Planned for 2019 A TransCanada official said the company will start building the Coastal GasLink pipeline early next year, pending a positive final investment decision (FID) on the linked LNG Canada project. “We would be looking at constructing in the early part of 2019,” Coastal Gaslink President Richard Gateman told Reuters, after the head of LNG Canada said construction of its $31 billion (C$40 billion) LNG export terminal should begin this year. “W “Wee could be doing a little bit of field work in the fall (of 2018), if there’s an FID decision.” LNG Canada is a joint venture among Royal Dutch Shell, PetroChina Co, Mitsubishi and Korea Gas. An FID is expected from the project partners this year. year. The $3.75 billion (C$4.8 billion) Coastal GasLink is a 670-km (415-mile) pipeline that would cross two mountain ranges to connect rich shale fields in Alberta and northeast British Columbia with the proposed LNG Canada export terminal on British Columbia’s Northwest Coast. TransCanada, which will own and operate the pipeline, expects to award contracts for the construction to four consortiums within the next two months, Gateman said. Those contractors will be a mix of local and international players with experience building in mountainous terrain, he said. �

Kingfisher, Ergon to Build Cimarron Express Pipeline Kingfisher Midstream, Blueknight Energy Partners and affiliates of Ergon have executed definitive agreements to form Cimarron Express Pipeline. The joint venture will include the construction and operation of a new crude oil pipeline serving STACK producers in central Oklahoma. The 65-mile, 16-inch pipeline, which will extend from northeastern Kingfisher County, Okla., to Blueknight’s crude oil terminal in Cushing, will provide direct market access for producers produ cers and will will have an initial initial capacity capacity of 90,000 bpd, expandable to over 175,000 bpd. It is expected to be completed in mid-2019. Under the terms of the agreement, Blueknight will construct and operate the pipeline, which will connect to Kingfisher ’s crude oil gathering system in northeastern Kingfisher County. Kingfisher and Ergon will each own 50% of Cimarron Express Pipeline. Concurrent with the formation of the joint venture, Alta Mesa executed a long-term acreage dedication and transportation agreement which incorporates about 120,000 net acres in Kingfisher and Garfield counties. 10

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Targa Resources has entered long-term, fee-based agreements for natural gas gathering and processing services in the Delaware Basin and for downstream transportation, fractionation and other related services. Targa said it will construct 220 miles of 12 to 24-inch, high-pressure, rich gas gathering pipelines across the Delaware Basin. The Falcon Plant, a new 250 MMcf/d cryogenic natural gas processing plant, is expected to begin beg in operat operation ionss in the fourt fourth h quarter quarter of 2019, 2019, and the Peregrine Plant – a second 250 MMcf/d cryogenic natural gas processing plant – should be onlin onlinee in the sec second ond quar quarter ter of 2020. 2020. The company also announced an extension of the Grand Prix NGL Pipeline, a new common carrier NGL pipeline currently under construction, into southern Oklahoma. Once completed, Grand Prix will run from North Texas, Texas, where Permian and Oklahoma volumes will be connected to a 30-inch segment, to Mont Belvieu, Texas. Initially, the pipeline it will be able to trans port 450, 450,000 000 bpd, bpd, with the abil ability ity to to expand expand to 950,000 bpd. Capacity on the 24-inch pipeline from the Permian Basin to North Texas will be about 300,000 bpd, with the ability to expand to 950,000 bpd. The capacity from southern Oklahoma to North Texas will vary based on telescoping pipe size.

Outrigger II Enters DJ Basin with Gathering System

Outrigger Energy II began development of a tri-stream system in Weld County, Colo., that will include wellhead natural gas TransCanada placed its Northwest gathering, a 60 MMcf/d cryogenic processMainline Loop-Boundary Lake pipeline in ing plant, field compressor stations, crude service, completing the final section of its oil gathering and produced water gathering. Outrigger will construct and operate the 2017 Expansion Program on the NOVA Gas system, which is anchored by long-term acreTransmission (NGTL) System. The natural gas pipeline system in Western Canada age dedications from Mallard Exploration. includes 15,110 miles (24,320 km) of pipeline Outrigger said it is also in advanced discussions with several other area producers and has and associated facilities. With the completion of winter construction formulated plans to expand the initial system. The company has purchased a new cryoactivities, the expansion program represents a $1.7 billion investment in Canadian natural genic plant and has begun the permitting process ss with Weld Coun County ty and the state of gas infrastructure and connects natural gas proce production produ ction from northw northwest est Alber Alberta ta and north north-- Colorado, with an in-service date targeted for early 2019. The processing plant will deliver east British Columbia to the NGTL System. The expansion added 143 miles (230 km) of residue gas to Cheyenne Plains Pipeline, a new pipeline and additional compression facili- 36-inch line that offers abundant access to Cheyennee Hub Hub and to Mid-Co Mid-Contine ntinent nt ties, increasing NGTL System capacity by 500 both the Cheyenn MMcf/d. The project generated about $800 markets, providing price and delivery advanmillion in labor income during its construction tages over other pipeline choices. NGLs will be delivered to the Overland phase pha se and and will will add add an estim estimate ated d $1.2 $1.2 billio billion n in Pass Pipeline operated by the Williams gross domestic product in Canada. The 2017 expansion program is part of Companies and co-owned by ONEOK, TransCanada’s commitment of more than Inc. Multiple outlet opportunities exist for $7 billion in near-term growth capital to add crude oil delivery, including Tallgrass’ Pony 2.5 Bcf/d in delivery capacity to the NGTL Express Pipeline system and NGL Energy’s Grand Mesa Pipeline system. System by 2021.

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PROJECTS

Portion of White Cliffs Converting to LNG SemGroup Corporation will convert a portion of the White Cliffs Pipeline system to NGL service and expand the system to reach markets in Texas. The project is supported by 10-year 10-yea r agreements with DCP Midstream and its affiliate, DCP Southern Hills Pipeline. “We are excited to execute this opportunity with DCP and provide a much-needed market solution to the DJ Basin, while at the same time optimizing White Cliffs to include both crude and NGL capabilities,” said David Minielly, Vice Vice President of SemGroup’s crude operations. “This project provides producers and natural gas processors with a costeffective and reliable solution to move valuable NGLs from Colorado to Mont Belvieu via Southern Hills Pipeline for processing and sale into the Gulf Coast marketplace.” SemGroup will convert one of White Cliffs’ 12-inch pipelines from crude service to NGL Y-grade Y-grade service. The pipeline will have an initial capacity of 90,000 bpd and be expandable up to 120,000 bpd. It will be taken out of service late in the first quarter of 2019 and is expected to resume operations by the end of the year. In addition, the company will construct a 12-mile extension south of Cushing to interconnect with DCP’s Southern Hills Pipeline and move NGLs to Mont Belvieu. The project is expected to cost between $60 million and $66 million. �

Centennial Plant Expanding to Accommodate Producers

Lilis Energy, Salt Creek Midstream Enter into Gathering Agreement

Sterling Energy Investments will expand the processing capacity and associated natural gas gathering pipeline infrastructure of its Centennial System in the northeastern DJ Basin to 220 MMcf/d to accommodate growing producer demand. In addition, the company said it will expand the capacity at its existing Centennial Gas Processing Plant by up to 120 MMcf/d. The permitting process is under way, and the project is expected begin service in the second half of 2019. Sterling’s Centennial System consists of more than 450 miles of low-pressure gathering pipeline, spanning Weld, Morgan, and Logan Counties in Colorado and Cheyenne County in Nebraska. It includes three interconnected natural gas proces pro ces sin sing g pla plants nts,, with eac each h pla nt con nected to a different downstream residue gas market to provide flow assurance for area producers. Residue gas takeaway is provid pro vid ed by Chey enn ennee Plai ns, Tallgr ass Interstate Gas Transmission and Southern Star pipelines. NGL takeaway is provided by Ove Overla rland nd Pas Passs Pipe lin line. e. As part of its investment in natural gas gathering and processing infrastructure in the DJ Basin, Sterling also recently com pleted the first phase of its Jackson Lake Processing Plant expansion and expects to complete the entire project during the fourth quarter of 2018.

Lilis Energy, an exploration and development company operating in the Permian Basin, entered into a crude oil gathering agreement with Salt Creek Midstream. The agreement supports Lilis’ efforts to secure long-term infrastructure solutions to move its oil production out of the Delaware Basin. Construction of the project is expected to commence immediately immediately with service to begin in 2019. Salt Creek is building a new regional pipeline system and will provide gathering and transportation service for Lilis’ oil production in Texas and New Mexico to the terminal in Winkler County, Texas. The Winkler terminal will allow Lilis to directly access long-haul downstream pipelines that are connected to Midland, Texas, Texas, and the Gulf Coast region. The project is supported by all of Lilis’ current acreage in Lea County, N.M., and Winkler and Loving counties in Texas. Lilis will provide its acreage dedication with no volume or capex commitments and Salt Creek will provide pro vide all cap capita itall for for the oil gat gather hering ing syst system. em. In addition to the crude oil gathering agreement, Lilis and Salt Creek also entered into an agreement whereby Lilis received cash consideration in exchange for granting Salt Creek options to provide certain natural gas midstream services for Lilis’ gas produced within an area of o f mutual interest. in terest. Salt Creek’s system will be constructed, managed and operated by ARM Midstream Management, an affiliate of ARM Energy.

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Enterprise, ETP Form JV to Restore Old Ocean Service Enterprise Products Partners and Energy Transfer Partners (ETP) formed a 50/50 joint venture to resume service on the Old Ocean natural gas pipeline. The 24-inch pipeline, which has been idled since 2012, originates at Maypearl, Texas, and extends south approximately 240 miles to Sweeny, Texas. Service is expected to resume in the second quarter of 2018 with ETP as the operator. Additionally, both parties are in the process of expanding their jointly owned North Texas 36-inch pipeline to increase capacity from West Texas for deliveries into the Old Ocean pipelin pip eline. e. The Nor North th Texas pipe pipelin linee expa expansi nsion on is expected to be completed near the end of 2018.

Nord Stream 2 Prep Begins Along German Coast A consortium of western companies and Russia’s Gazprom said it has started preparatory work in Greifswald Bay off Germany’s Baltic coast for construction of the subsea Nord Stream 2 gas pipeline pipeline to Germany. Germany. “Five dredgers are now working on the trench for the two pipeline strings,” the consortium, based in Switzerland’s Zug, said in a news release. “Preparatory works are in accordance with the Stralsund mining authority’s planning approval.” The regulatory authority granted the consortium a permit in January to build the pipeline in German territorial waters. Gazprom’s Western partners are energy companies Uniper, Wintershall, Engie, Austria’s OMV, and Anglo-Dutch Anglo-Dutch group Shell. The Nord Stream 2 project has said it will tap banks for financing in the fourth quarter of 2018 or early next year.

Apache, Salt Creek to Build SCM Alpine Header System Apache Midstream and Salt Creek Midstream, an affiliate of ARM Energy, are developing SCM Alpine, a 445,000 bpd header system comprised of two pipeline segments originating at the companies’ processing facilities in Reeves County, Texas. Texas. SCM Alpine will transport NGLs to Waha, Texas, where the system will interconnect to downstream pipelines providi pro viding ng acc access ess to fra fractio ctionat nation ion fac facili ilitie tiess at Mont Belvieu and Corpus Christi, Texas. Construction Constructio n has begun, and the system is expected to be operational in first quarter of 2019, according to the companies. In addition, Apache Midstream has signed an option to acquire a 50% stake in the $100 million project, which is supported by 10-year commitments from both Salt Creek and Apache. ARM Midstream, an affiliate of ARM Energy, will construct, manage and operate the system. P&GJ

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LEGAL PERSPECTIVES

Lines Between Regulators Still Blurry for Midstream Processors

Nichols

Ewing

By Robert Nichols and Nichols and Kevin Ewing, Bracewell LLP, Houston LLP, Houston and Washington

T

he Pipeline and Hazardous Materials Safety Administration (PHMSA) began an effort in i n 2014 to help businesses engaged in midstream oil and gas processing operations determine where the lines fall between applicability of PHMSA safety rules and Occupational Safety and Health Administration (OSHA) regulation, particularly OSHA’s process safety management (PSM) standard. As a result, a working group of PHMSA and industry representatives offered pro posed guidance in August 2015 in the form of FAQs. Although PHMSA has never published the guidance as official agency policy,, while cautioning it does not carry policy the force of law, its staff has confirmed that both of the agencies are referencing that working group’s guidance when questions of coverage arise. Further, PHMSA is considering how to publicize that guidance to industry and others through its agency website. Accordingly, companies conducting midstream processing operations should regard that guidance as important to understanding when PSM applies, and does not apply, to their assets.

Background on Jurisdictional Scope The Office of Pipeline Safety (OPS) was created by Congress in September 1968 and housed within the U.S. Department of Transportation (DOT), to administer the Naturall Gas Pipelin Natura Pipelinee Safety Act, which had been enact enacted ed that that same year year.. Unde Underr that law law,, the agency was given authority to regulate pipeline pipeli ne transp transportatio ortation n of natur natural al (flamma (flammable, toxic, toxic, or corrosive) corrosive) gas gas and other other gases. gases. Nine years later, with the enactment of the Hazardous Liquid Pipeline Safety Act of 1979, Congress conferred jurisdiction on the OPS with regard to pipelines carrying hazardous liquids such as crude oil. As part of a 2004 reorganization of pipeline safety regulation, r egulation, PHMSA was created by Congress to regulate both both pipeline safety safety and the safe transportation of hazardous materials by other modes. Importantly Importantly,, PHMSA is not tasked generally with safeguarding occupational safety, but with public safety and health, as well as environmental concerns associated with transportation 14

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of hazardous materials. Congress did not pass legislation intended to broadly regulate occupational safety and health until the enactment of the Occupational Safety and Health (OSH) Act of 1970. Along with that act, Congress Congress also created OSHA to set standards and pursue enforcement. Unlike PHMSA’s narrower scope, OSHA has broad authority for safety and health in industry, construction and other sectors. It focuses primarily primarily on safety measures related to activities, such as protective equipment for welding, rather than on business sectors. Despite its broad mandate, Congress did not intend OSHA to supplant safety jurisdiction of other agencies with more specific authority over particular industries. Accordingly, Congress provided in Section 4(b)(1) of the OSH Act that nothing in that law would “apply to working conditions of employees with respect to which other Federal agencies . . . exercise statutory authority to prescribe or enforce standards or regulations affecting occupational safety or health.” In the first years of case law development under the OSH Act, some federal courts suggested that the Section 4(b)(1) preemption provision meant that the pipeline industry and others enjoyed broad preemption of OSHA jurisdiction because of more specific safety regulation conferred on DOT agencies. In 2002, however, the U.S. Supreme Court in Chao v. Mallard Bay Drilling adopted a relatively narrow view of that provision, and there was no longer any argument to be made that oil and gas pipeline and related operations enjoyed any general preemption from OSHA jurisdiction. The federal agencies involved had long been aware that Section 4(b)(1) would create questions about the delineation between OSHA and DOT jurisdictions. Soon after its creation in 1972, OSHA began communicating with the DOT about Section 4(b) (1) preemption issues and, since then, has sought to coordinate with other agencies about when particular OSHA regulations are preempted in the pipeline industry or other DOT-regulated businesses.

Midstream Issues One particularly important jurisdiction-

al question that arose in the 1990s was when (OSHA’s PSM standard) codified at 29 C.F.R. Section 1910.119 was applicable to midstream operations. PSM is a complex performance-based standard that generally applies to facilities conducting a process that uses a highly hazardous chemical in quantities over specified threshold amounts. PSM regulation is aimed at preventing releases of hazardous chemicals creating fire, explosion, toxicity or other hazards. Regarding midstream oil and gas industry, OSHA concluded in 1992 after communications with DOT that PSM regulation was not applicable to “natural gas distribution and transportation facilities.” In that interpretation, OSHA explained that the inapplicability of PSM to those activities was justified because “OPS regulations address[ed] the hazards of fire and explosion in the gas distribution and transmission process.” This interpretation anticipated the ruling in Mallard Bay ten years later. With respect to gas processing operations, as opposed to transportation, OSHA, with the agreement of PHMSA, adopted a different view as to PSM coverage. Specifically, in a February 2005 interpretation letter, OSHA rejected the view that “gas processing should be excluded from [PSM] coverage.” In the letter, OSHA instructed that the agency “believes that gas plants are appropriately covered by the process safety safet y management standard.” Despite this guidance, where the precise lines fall with regard to PSM applicability to midstream assets has remained a concern because the exact demarcation between betwe en proce processing ssing and trans transport portatio ation n operations is often unclear.

FAQ Guidelines In August 2015, PHMSA’s working group proposed seven questions and answers intended to offer guidance on these coverage questions. questions. The following excerpts provide a view of this guidance: How does one delineate the boundary between pipeline transportation and a processing facility? “PHMSA Policy indicates that it will not

provide regulatory oversight oversight under PHMSA PHMSA Part 192 and 195 for pipelines downstream of the first pressure control device entering the processing facility, and upstream of the last pressure control device leaving the processing facility...” How does PHMSA Policy apply regulatory oversight to piping that bypasses processing downstream downstream of the first pressure control device? “Piping that is downstream of the first pressure control device that is occasionally used to bypass processing is subject to regulatory oversight under OSHA PSM. Piping that is downstream of the first pressure control device that is predominantly used to bypass processing is subject to regulatory oversight under PHMSA Part 192 or 195.” On the issue of regulatory coverage of a pipeline entering a processing facility that bypasses a pressure control device. With respect to that issue, the FAQ explained that: “A pipeline that predominantly bypasses a pressure control device is subject to the regulatory oversight under PHMSA Part 192 or 195. Similarly Similarly,, if a pipeline bypasses a facility that is no longer in service, the pipeline would be subject to regulatory

oversight under PHMSA Part 192 or 195.” Notably,, the proposed guidance consid Notably ered another difficult question related to midstream facilities—specifically, PSM coverage of underground storage and associated piping. With respect respect to that issue, the proposed guidance guidance explains: “Piping associated with underground storage used for the ‘purpose of managing processing facility inventory’ is subject to regulatory oversight under OSHA PSM. Piping associated with storage caverns used for transportation is subject to regulatory oversight under PHMSA Part 192 or 195. States with underground storage laws regulate the undergroun underground d storage.” As evidenced by the questions and answers considered above, this proposed 2015 FAQ included valuable information concerning delineation of PHMSA vs. OSHA/PSM coverage. However, the subcommittee was careful to frame this draft guidance as only a “proposal” to be submitted to the Joint Advisory Committees for consideration. It was further emphasized during a 2015 meeti ng of the PHMSA Joint Advisory Committee that this guidance, even if adopted, would not have the force of law.

Conclusion

The uncertainties as to when OSHA’s PSM standard, as opposed to PHMSA regulations, apply to midstream processing operations, has not been resolved through notice-and-comment regulations or other binding legal authority authority.. Nonetheless, the policy guidance that PHMSA and OSHA are currently utilizing offers industry some meaningful, albeit nonbinding, instruction into where the lines fall. P&GJ Authors: Robert “Bob” Nichols is a partner in Bracewell’s Houston office, repre sents employers employers in litigation, administrative administrative investigations and inspections, and other actions concerning alleged occupational safety and health violations, discrimination, retaliation, harassment, wrongful discharge, and other employment concerns Ke vin Kevi n Ew in ing g is a partner in the Washington office of Bracewell. He advises energy and infrastructure companies pursuing pursui ng develo development pment projects projects,, feder federal al authorizations, or changes in agency policy, or responding to Executive Branch inquiries and enforcement.

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Memphis Utility Makes Big Inroads in 30-Year Replacement Plan By Michael Reed, Managing Editor

A

s the largest three-service munici pal utility in the United States, Memphis Light, Gas and Water (MLGW) faces a myriad of com plicated decisions concerning con cerning the repair and maintenance of infrastructure throughout Shelby County, Coun ty, Tenn. Tenn.

cast-iron mains,” Weaver said. When possible, if the work includes disThe first cast-iron mains addressed were in connecting services, MLGW tries to notify the company’s high-pressure system, which the customer through a letter to their home or operates between 61 and 99 psig, and the medi- business 14 days in advance. When that’s that’s not um-pressure system, which operates between possible at least seven days notice notice is given. For road closures, the company notifies 31 and 60 psig. These two systems were deemed to have the higher possibility of leaks. the local media and distributes the informa Next, Nex t, MLG MLGW W foc focuse used d on on inte interme rmedia diatete-pres pres-- tion through MLGW social media platforms. In emergency situations, an auto-dialer sure lines, which operate between 15 and 30 psig, psi g, and and the the comp company any’’s standa standardrd-pres pressur suree syssys- sends a recorded message to the customer’s on-file phone number. In some cases, notictem, which operates at about one-quarter psig. As with other utilities in major cities, the es are distributed door-to-door. In order to limit the amount of digging company’s replacement and maintenance efforts require negotiating areas of con- required, MLGW uses horizontal directiongestion both above-ground (schools, three al drilling whenever possible. Additionally, hospitals and a zoo, among them), and guided-wave (GW) technology is used to below-ground, within with in street rights-of-ways. detect anomalies and potential leaks within the transmission system. The company also relies on steel service “THE BIGGER BIGGER CHALLENGE CHALLENGE taps to integrate a transition from steel to polyethylene (PE), and uses excess flow IS WITHIN THE An MLGW worker valves into the tapping tees for new conoperates a jack struction of services and gas distribution NEIGHBORHOODS NEIGHBORHOOD S THEMSELVES ... hammer in Shelby mains that have been replaced with steel. County, Tenn THESE ARE PRETTY MUCH “This fitting reduces the number of cou plings pli ngs nee needed ded to tran transfe sferr the the servic servicee to the new ONE-LANE, ONE-WAY STREETS Founded in 1939, among the company’s gas main. Only one coupling is needed to conchief concerns is the safety of its gas disnect the service pipe to the tee,” Weaver said. THAT ARE MADE INACCESSIBLE.” tribution system, particularly the 330 miles Some of the cast-iron replacement will rely of cast-iron gas mains it began replacing on coated welded steel instead of PE, he added. — ALONZO WEAVER , MEMPHIS LIGHT, in 1992 as part of a $100 million program. Weaver, who graduated high school in GAS AND WATER “Basically, we are removing pipe and any 1979, discovered his future career path in services that we came across that required energy at a relatively young age. He worked replacement,” said Alonzo Weaver, vice “The bigger challenge is within the as an intern in construction and maintenance president presid ent of MLGW’s Engin Engineering eering and neighborhoods themselves,” Weaver said. at MLGW during the summer break while in Operations Department. “There are some “Some of these are older communities, and college at Rensselaer Polytechnic Institute, coupling issues, but overall, eliminating the you have to open up a series of holes out in in Troy, N.Y., where he earned a bachelor’s cast-iron is the main focus.” the streets. These are pretty much one-lane, degree in mechanical engineering. The overall effort calls for all cast-iron to one-way streets that are made inaccessible.” “I pretty much interviewed with utilities be eliminated eliminated from from the system system by 2021. W With ith Some of these streets, where there were from that point going forward,” he said. “I about 10 miles of replacement work left to do pocke pockets ts of cast cast iron infras infrastructu tructure re dating dating back found out there was a lot involved in getting on 10- and 16-inch pipes, this puts the com- to 1956, were deemed to be among the highest electric, gas and water to the customers, and pany right right on schedu schedule. le. priorities prior ities for the progr program. am. To avoid as much that it was pretty interesting work.” Along with cast-iron replacement the inconvenience as possible, the corporate comMLGW,, which employs about MLGW ab out 2,600 peocompany plans to eliminate all the wrought munications department had to be proactive. ple, has remained active in offering interniron and PVC gas pipes from its gas dis“It takes a lot of communications, and we ships and maintaining a co-op program over tribution systems. This effort will be com- put out lette letters rs on the the timing timing of stree streett closures, closures, the years, which Weaver said “has paid off pleted by 2021 as well. The wrought-iron sometimes a month or two in advance,” very well for both us and for the students.” still remaining in the system covers about 2 Weaver said. “The work is very weatherWeaver joined MLGW in 1983 as an miles and consists of 2- and 4-inch mains. driven, though. You can put out information a engineering assistant in Electric Operations “MLGW eliminated all of its standard month in advance, but still have to follow up and was promoted to operations assistant in pressure system syste m this fall, which was mainly main ly and deal with possible changes.” that department in 1987. He completed the 16

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MLGW Executive Development Program in 1988 and received an MBA from the University of Memphis in 1997. In his current position, Weaver is responsible for managing and coordinating all engineering functions, including commercial and residential engineering, as well as electric, gas and water operations. He is also responsible for water quality assurance and systems operations. Weaver said the work has remained rewarding throughout his career, but that doesn’t mean his job doesn’t come with some stressful moments. In addition to gas operations, he is the “crisis management guy” on the electric side. That entails dealing with situations such as customer service outages and restoration efforts following storms. “As far as gas is concerned, making sure we are on top of all the regulations and that we keep a safe system is my top concern,” he said. “Our gas operations have a tremendous safety record, but all it takes is one or two incidents to tarnish that. We realize we don’t have a lot of room for error on that.”

A Little History While Memphis Light, Gas and Water

has been in existence since 1939, its parent companies started well over 100 years ago, getting its start not long after the Civil War. Memphis’ first utility company was the Memphis Gas Light Company, formed in 1852 and serving about 10,000 people in only a three-square-mile area. The “electric age” began at about that same time, ushReplacing ering in the use of powere pow ered d ligh light, t, app appliliance and other home and business conveniences. To serve that need, Memphis Light and Power Company was formed. In 1902, the company merged with the city’s only natural gas distributor, and by 1917, the city’s two competing gas and electric companies consolidated,

older gas mains, a process that began in 1992.

eventually becoming Memphis Power and Light. The city of Memphis bought privately owned Memphis Power and Light in 1939, and Memphis Light, Gas and Water was formed, creating what is now the largest threeservice public utility in the nation. P&GJ

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| 17

What a Gas Measurement Technician Needs to Know for Success By James N. Witte, Staff Engineer, Southwest Research Institute

T

he position of measurement technician is one of the most important roles in the transmission pipeline operation. The measurement technician is an operator that is assigned the responsibility for the maintenance and operation of several gas metering and regulation stations in a defined geographic region. Usually, there are several requirements that go along with this responsibility. This article discusses those requirements and the knowledge and skills that a measurement technician must possess to be successful. Unlike many pipeline jobs, the measurement technician is required to work alone with responsibility for large geographic areas. Success in this role requires the focus and self-motivation to perform quality work and the expertise to maintain and safely operate metering stations. Because technicians are often the only employees who interact regularly with customers, they often serve as the de facto company representative and must respond promptly and courteously to any concerns. As a result, the quality of a measurement technician’s training, performance and expressions of job satisfaction may influence how customers view the company and

directly affect its operational goals, profitability and reputation. The typical measurement technician is assigned responsibility for 25-35 metering stations in a service area and provided a vehicle with all the tools necessary for the job. The high-mileage associated with the job requires vehicle replacement approximately every three years, but these intervals can be shortened when corporate mergers result in larger geographic areas. The technician must conduct tests of the meters on a scheduled basis. Often these require notice to a witness from another company in advance of the test. Everything that is done to affect the performance of a gas meter station must be documented and communicated to the main office on a timely basis. Commercial transactions in the natural gas industry require a monthly accounting close, and the results of the meter tests and verifications must be reported with sufficient time to accommodate closing in order to avoid prior period adjustments (PPA). PPAs require corrections to financial transactions between two or more commercial entities and must be minimized, because these transactions must precisely equate to a pre-scheduled value.

Some company structures will differentiate the technician duties by making some responsible for only regulators and control valves. Also, there may be a separation of duties related to communications because that job may require special communications licensing and qualification. In addition to maintaining the metering stations, the technician is also responsible for gas quality enforcement. Gas sampling to determine the composition of the gas and the concentrations of contaminants, such as hydrogen sulfide, water vapor, and other objectionable materials, is required to comply with applicable gas transportation tariffs. The technician must not only have knowledge of the gas quality test methods, but must also know the gas quality requirements in the tariff and gas contract. Analysis and troubleshooting is important in this role, so a successful technician will have multi-disciplinary skills in electronics, mechanical engineering technology, mathematics and basic chemistry, as well as the ability to use computers, read schematics and engineering drawings, and comprehend technical manuals. The technician also is usually required to understand closed-loop control theory and how to tune the control loops for optimum performance.

Work Force Changes The industry is presently going through a significant amount of knowledge change as technicians with 20-30 years of experience are retiring and being replaced by inexperienced new hires. This poses a challenge for pipeline companies, because problemsolving ability is essential to a measurement technician’s success, and this type of knowledge is typically gained through on-the-job experience. Sometimes, the job transition to the new hire is done without a full transference of knowledge from the retiring technician. It is clear that results will vary depending on the focus of management to allow transition time for the on-boarding of the new technician and the beginning aptitude of the candidate technician. A suggested allowance for the transition is one year, with a lot of daily interface time with the experienced technician. In addition to formal training, new measurement technicians must be willing to 18

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engage the seasoned technicians and learn from their experience. Of course, no technician will ever know it all, and it is important to learn through individual study and experience. But engaging senior technicians, engineers, software programmers and vendor technical representatives can accelerate applied knowledge.

best practice is to capture screen shots and assemble a step-by-step description of how to accomplish different tasks. This may speed up the recognition of items that have changed by software version.

Technician Training In 2010, the Transmission Measurement

Committee of the American Gas Association produced a white paper, “Natural Gas Measurement Technician Training and Development Guidelines.” This document attempted to capture the body of knowledge necessary to define a path to competency. It also presented an estimate of the num ber of hours required for training to occur

The Equipment When today’s retirees first entered the workforce, technicians needed a strong knowledge of mechanical and pneumatic devices, and their most commonly used tools might have been an adjustable wrench or a screwdriver for making fine adjustments at metering and regulating stations. Today, the most used tool by a measurement technician is a laptop computer, as current pipeline operations incorporate a higher degree of electronic and computer-based field equipment. Today’ss technician typically Today’ typica lly relies on cor porate support groups, such as Supervisory Control and Data Acquisition (SCADA) and Corporate Measurement. They require custom analytical tools for data analysis, data archival, process trending, and application-specific software. Many of the newer technologies, such as ultrasonic flow meters, provide the opportunity to assess the operational health of the meter and produce custom reports. Interpretation of those reports is a very important skill for the technician to master. The technology transition has been a constant challenge for the baby boomers. The older technicians might have often been intimidated by microprocesso microprocessor-based r-based equipment or might not have possessed good computer skills. In this regard, there is a great deal of contrast between the millennials’ willing acceptance of new technologies and that of the outgoing class of technicians. The technician will have several metering stations with the newer technologies and several with some of the older technologies. This makes the job more challenging, since the technician will have to know how to operate, maintain, and troubleshoot both old and new equipment. The older equipment may require service parts that are no longer available, and it may be challenging for a new technician to determine where a predecessorr stored the surplus parts. predecesso Another challenge the new measurement technician must face is to learn and master operator interface software changes and flow computer software changes. Often, the software changes are made by a programmer who does not have to use the software or operate the equipment to which it interfaces. An oldfashioned solution to this concern is to keep a notebook handy for reference; a www.pgjonline.com

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expressed on a task basis. The information was presented in this manner to allow the path to competency to be customized based on the equipment that a technician would have to operate and maintain. The basic knowledge level items were described as operate, maintain, or install. The advanced level items were described using the terms troubleshoot t roubleshoot and repair. The requirements for complete competency, on the basis of the white paper, projected that some three to five years would be required to reach full competency. Competency was judged as the ability of the technician to execute the various tasks by himself without oversight by a supervisor or t rainer rainer.. Many companies are now requiring an associate degree in electrical technology or mechanical technology. Unfortunat Unfortunately, ely, as already noted, the rest of the knowledge requirements for the job are just not taught in colleges. The additional knowledge allows the technician to understand how the meter station operates and to understand when problems might affect measurement accuracy. To a certain degree, the technician develops a deductive intuition when a problem is developing. Other than task-oriented knowledge, the technician must also know and understand the requirements of all applicable industry metering standards and recommended practices. Many of these documents are named in contracts between the parties and gas transportation tariffs. The technician needs to read and understand these industry metering standards. Every year, there are several regional schools in the United States that offer technical courses on a variety of gas measurement topics and hands-on training specific to equipment that the technician operates, including: the International School of Hydrocarbon Measurement, American School of Gas Measurement Technology, Technology, Appalachian Gas Measurement Short Course, Acadiana Gas Measurement Short Course and Western Gas Measurement Short Course. The measurement equipment manufacturers also have some very good training classes in which they provide very detailed instructions on equipment operation, trou bleshooting and repair. repair.

Communications The technician must communicate effec-

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tively with a number of people who have varying responsibilities and information needs. Internally, these include meter analysts, system balance analysts, corporate measurement engineers, gas control and project managers. It is important that the technician be able to describe through detailed written communication what an observed problem proble m was, what action actionss were taken and what was the outcome of those actions. Because measurement is the transactional basis, bas is, the tec technic hnician ian can cannot not simp simply ly fix fix a prob prob-lem without communicating the fact. All of the reporting must be complete and factual. Through effective communication, litigation between betw een the comp compani anies es may may be avoid avoided. ed. It is important that the technician communicate schedule changes to test witnesses when trouble happens. Otherwise, the witnesses will be needlessly wasting time waiting for a test that may not happen that day. This communication is appreciated by measurement technicians of all companies, and usually because of this, opportunities for learning occur through these verbal communications.

Recordkeeping The measurement technician is involved with every aspect of recordkeeping as long as he has responsibility for the metering or regulating asset. The technician requests a meter number assignment prior to commissioning any new facility. Upon station startup, his documentation is used to configure the new meter in the gas measurement system. He must fill out a report for any and all changes to the meter station, meter verifications, and customerrequested special tests. The technician is also responsible for all of the documentation to support the required U.S. Department of Transportation (DOT) verifications of gas regulators, over pressure protection devices and gas control system pressure measurement point-to point readings. The technician must be certain to be current with the necessary documentation. The current best practice is to use smart electronic forms that prompt the technician for the data input. Regardless of what activities are happening, the technician still has the obligation to complete the DOT inspections as scheduled.

Other Considerations Industry associates were polled in preparation of this paper and provided quite a few opinions on the topic of what a gas measurement technician needs to know to be successful. Here are a few f ew of the comments that were received: The technicians need to take pride in their work. The technician must stay current on new metering technologies. technologies. This is often done done

through attendance at any of the several industry gas measurement schools offered across the nation. They must read, read, read, and learn as much as they can. “The answer is in the manual.” Technicians will never know it all, so ask for training when needed. The measurement technician might be unrecognized in the company until trouble happens, but then becomes well-known throughout the company. When trouble happens, the technician is always the first to arrive at the meter station and the last to leave.

Conclusions The gas measurement technician job is arguably the most important job on the pipeline. Through the technician’ technician’ss efforts, the gas measurement is safe and accurate, system lost-and-unaccounted-for gas is minimal, and transactions occur daily with a high confidence in their integrity integrity.. The knowledge base required for the measurement technician is very broad and challenging. Every day day is a new learning opportunity for the technician, and no one is going to know it all. To be successful, technicians must be honest, possess good analytical skills, learn how to troubleshoot, communicate com pletely and factually factually,, and have a desire to be continually improving. They also need to seek out opportunities to learn more about the measurement technologies and processes of their company. company. Acknowledgements: The author would like to recognize the knowledgeable and insightful contributions of the following individuals toward the preparation of this paper.. These contributors are listed as paper follows: Phil Martin, Kinder Morgan; Joe North, Kinder Morgan; and David Woods, Southwestern Gas. P&GJ Aut hor : Jam es N.

is a graduate engineer with 30 years of natural gas and pet role um pro du ct me as ure ment experience. He h as b een act iv iveely in the advancement of natural gas measurement practices through his leadership roles in the Ame ric an G as Asso A ssoci ciati ati on Trans Tr ansmi missi ssi on Me as ure me nt Co mm it te e an d th e Pip eli ne Rese R ese arch C oun cil In Inter ter nat ion al Me as ure me nt Tech ni ca l Co mm it te e. Witte currently serves as staff engineer for th thee Sou South thwes wes t Res earc earch h In Insti sti tu tute’s te’s Fl ui ds an d Ma ch in er y En gi ne er erin in g Depa De part rtme ment nt , Me Mech chan anic ical al En Engi gi nee ri ng Divis Di vis io ion, n, in San Ant oni o. Witte

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Nigeria Makes Progress on Delayed Gas Pipeline Project

By Shem Oirere

N

igeria has announced progress on a electricity-starved northern part. The country’s oil and gas operator key gas pipeline project that is seen as part of the country’s difficult bal- Nigerian National Petroleum Corporation ancing act between increasing natu- (NNPC) has awarded the two-party conral gas production to 11,000 MMcf/d by the sortium of Nigerian-based Oando Plc end of 2018 and creating adequate domestic and United Arab Emirates-headquartered demand to consume the increased volumes. Oilserv Limited the EPC contract for the Nigeria, Nige ria, whic which h has the larg largest est prov en first phase of the $2.8 billion AKK pipenatural gas reserves in Africa estimated line system, involving the 134-mile (215at 187 Tcf and a possible but yet undis- km) pipeline stretching from Ajaokuta to covered potential for 600 Tcf, has picked Abuja, which includes a terminal gas statwo consortia as preferred engineering, tion, metering, pigging and block valve proc urem urement ent and con constru structi ction on (EPC (EPC)) conc on- provisions. The 100% contractor financing tractors for two sections of the 382-mile modeled tender is worth $727 million. (614-km) Ajaokuta-Kaduna-Kano (AKK) A similar EPC contract for the third phase gas pipeline to link the country’s gas-rich of the 40-inch pipeline project involving the region to the populated, industrialized but 137-mile (221-km) section linking Kaduna and Kano terminal gas stations has been awarded to another two-party consortium – Nigeria’s Brentex Petroleum Services Limited and Chinese energy contractor China Petroleum Pipeline Bureaux – at a cost of $1.2 billion. NNPC has deferred the award of Lot 2 of the contract covering 120 miles (193 km) of the AKK pipeline to be confirmed later. Like in other previous Nigerian gas pipe line pro project jects, s, the two con consort sort ia are expected to carry out contract specified engineering design of the pipeline, the right-of-way survey with the support of the government, right-of-way acquisition, pigging, trenching and drilling hole works, delivery and stringing of pipe s, weld ing of line pipe s and coat ing, lowering of welded pipes into prepared trenches, and back-filling. However, both NNPC and parties of the two consortia could not immediately confirm timelines for achieving these tasks and other details such as possible sub-contractors, material and equipment supply and anticipated number of jobs to be crea ted dur during ing the cons truc tion , opera o pera tion and maintenance phases. Nigeria’s Federal Ministry of Petroleum Resources listed the project as one of the nine critical gas infrastructure initiatives that the government has given priority under country’s national gas policy that was released last year. The other eight gas transmission projects are the Aba-Owerri-Nnewi-Onitsha,

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Calabar-Ajaokuta, ELP-Ibadan-Jebba, Obiafu-Obrikom-Oben, expansion of ELP Phase 2, Oso Platform to QIT, Erha/Bosi and the Trans Sahara Gas Pipeline. The award of AKK’s Lot 1 and Lot 3 contracts is not only a key phase in the implementation of the 2008-approved Nigerian gas master plan, which partly targets reduction of the current flaring levels estimated at 50% of the natural gas and the nearly 12% of it that is injected to facilitate crude oil recovery, but also a link the nation’s gas pipeline to the rest of Africa and Europe. The plan is part of Nigeria’s 30-year Nigerian Integrated Infrastructure Master Plan to support infrastructure development in specific economic sectors, such as the oil and gas, for the 2013-2043 period. Lack of reliable gas transmission pipelines has been blamed for Nigeria’s lowcapacity electricity generation despite more than 80% of the country’s power generation plants being gas-fired. Nige Ni ge ri a’s na tu ra l ga s- fi re d po we werr pla nts hav e a nam namepl epl ate cap aci ty o f mo re than 11,600 MW but only 7,445 MW are either operational or partially operational with an estimated 4,990 MW being available according to government statistics. Actual electricity available from these gas-fired plants at times goes below 3,900 MW. Nigeri Nig eri a, whi which ch pro duc es a mer e 25% of its proven natural gas reserves, has about 23 gas-fired electricity generation pla nts of whi ch thr ee are ful ly ope rational, five are not in operation and 15 are operating partially due to a lack of infrastructure maintenance and adequate gas supply. The country’s latest national gas policy document said Nigeria failed to achieve “a full-blown domestic market by 2015” as envisaged in the gas master plan. The document added the “Plan has not delivered on all its set targets” and that the country “still lacks critical gas infrastructure and continues to fall short of domestic gas supply obligations.” “Nigeria is experiencing a full-blown energy crisis in spite of its abundant gas resources (and) a new gas policy that is more effective and adjusted for the much

harsher international business environment for gas is required to drive the reforms necessary to attract investment into the sector,” according to the national gas policy document. With the government estimating electricity demand at 12,800 MW and financing being sought for the biggest gas-fired power plant project, Azuri Thermal T hermal power po wer station, statio n, which is projected to have capacity of 1500 MW when fully complete, additional pipeline infrastructure is critical in Nigeria. “For so long, NNPC had activated an aggressive gas reforms and implementation drive, requiring accelerated implementation of gas pipeline infrastructure development with specific focus on critical pipeline infrastructure to power plants and industries,” said Ndu Ugh ama amadu du,, NNPC ’s Gro Group up Gen Genera era l Manager, Group Public Affairs Division, in early April. Currently, NNPC’s affiliate Nigeria Gas Company Ltd, owns and operates nearly 777 miles (1250 km) of gas pipeline with the rest being operated by Shell Nigeria Gas and Gaslink Nigeria Ltd, which are units of

Shell Petroleum Development Company mence in Nigeria’s Warri region and lay it Ltd and Oando Nigeria Ltd., respectively. north via Niger to Hassi R’Mel in Algeria Existing key gas pipeline network in befo re con connect nect ing it with the exis ting Nigeria include the Escravos-Lagos link to Trans-Mediterranean, Maghreb-Europe, the West, Oben-Ajaokuta to the North and Medgaz and Galsi pipelines. Nigeria Nige ria had earl earlier ier said it allo cate d Alakiri-Obigbo-Ikot-Abasi to the East. NNPC said AKK is key “in forming $400 million for the project in addition to the primary foundation for the planned the $450 million raised more than three Trans-Sahara Gas Pipeline project.” This years ago through Euro-bonds. The pipetranscontinental project is being developed line, which is expected to be 48 inches by Nigeria, Niger and Algeria, and will ter- on some sections and 56 inches in others, minate in Spain. was previously estimated to cost more It involves construction of 2,736 miles than $23.7 million. (4,401 km) of gas pipeline through For Nigeria to achieve the 30,000 Nig eri a, Nig Niger er and Alg Algeri eri a to Spa in. The MMcf/d natural gas production by 2043 pip eli ne wil l inc lud e 644 mil miles es (1, 037 and meet the national electricity demand km) in Nigeria, 523 miles (841 km) in of more than 12,800 MW, a sustainable Nig er, 1,4 30 mil miles es (2, 302 km) in Alge A lge ria gas infrastructure, particularly qualand 137 miles (220 km) in Spain, and ity gas transmission systems, is almost transport an estimated 30 billion cubic mandatory. liters of natural gas. Author: Shem Oirere is a freelance jourInitially, the plan called for the pipe- nalist based in Nairobi, Kenya. He holds line to be online this year under a part- advance diplomats in journalism from nership of NNPC, Algeria’s Sonatrach London School of Journalism and in Human and Niger’s National Oil Company. The Resource Management in International deadline now looks unlikely to be met. Relations and Diplomacy from the The plan is to have the gas pipeline com- University of South Africa. P&GJ

www.pgjonline.com

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DIGITAL OILFIELD

Nemec

Innovation, Technology Reshape North Dakota’s Bakken Shale

By Richard Nemec, Contributing Editor

W

hile North Dakota was riding out the most recent boom-bust cycle in the oil patch, energy industry officials in the state were learning on the job, trying to figure out ways to work smarter as margins and cash flows were dissipating for everyone. Before the turnaround developed this year, the oilfield was strewn with casualties. Nevertheless, billionaire oil pioneer pi oneer Harold Harol d Hamm and his teams at Continental Energy Resources Corp. looked around and saw opportunities to create better mousetraps in exploring and producing oil and natural gas. That’s why as prices continued to turn upward in 2018, by nearly mid-year the outlook in the Bakken Shale smelled like growth. The average drilling rig was doing the equivalent work of three before the price downturn in 2014-16. Drilling times from spud to completion of new wells were slashed to less than two weeks. Hydraulic fracturing has become faster and more productive. “The price crash was probably the best thing for the industry; we never would have gained the efficiencies that we have today without it,” Hamm, who has separate engineering and geology departments named for him at two state universities in North Dakota, told the Williston Basin Petroleum Conference (WBPC) in late May in Bismarck. “We decided we would keep our teams together, not lay anyone off, and we didn’t. We kept it together and gained efficiencies you would not believe. “We brought the cost of producing a barrel of Bakken crude down to a breakeven price of $26/bbl,” says Hamm while reminiscing about his early days in the Bakken as an Oklahoma-nurtured young entrepreneur in the oil patch. He noted that the Bakken Shale is a good place to be an “explorationist.” Other speakers at the North Dakota conference underscored the growing bullishness among industry leaders as the national head of the U.S. Energy Information Administration (EIA) Linda Capuano reported that she expects continued record natural gas production, further moderating U.S. gas prices. The EIA administrator sees oil production worldwide increasing by 2.4 million b/d b/ d this year and 2.2 million millio n 24

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b/d next year. Correspondingly, U.S. net oil imports will continue to decrease while exports keep rising, Capuano says. At the state level, Lynn Helms, oil/gas supervisor and director of the Department of Mineral Resources, carried out discussions with many of the key producers to shape the basics of his outlook, calling for moderate rig count growth into 2020 and

billion in the pipeline pi peline for new gas gathering g athering and processing infrastructure through the end of 2019, but there is a real need for more gas transmission capacity and eventually another oil pipeline the equivalent of the Dakota Access Pipeline (DAPL), which is operating at near-maximum capacity while court challenges trying to stop its operations are still active. “One of the things we have to start thinking about seriously is how our future “I NNOVATION, NOT REGULATIONS” oil supplies are going to get out of North Dakota,” Helms says. Noting that the state IS HOW WE CHOOSE TO SEE OUR in 2018 has excess pipeline and rail capacity, he says that based on current production growth projections, by 2020 there will be GOVERNMENT’S ROLE, AND WE TR TRY Y no more excess. An expanded DAPL and added refining capacity in the state won’t TO NARRO NARROW W DOWN WHAT WE’RE meet the need lying ahead. “Either we return to using a lot of rail cars, or we need ALL ABOUT INTO SIX WORDS: to begin two years ago planning the next crude pipeline out of the basin. That means the proposed Keystone XL or some other EMPOWER PEOPLE, IMPROVE LIVES options that industry has in mind.” For Helms and other operators, such as AND INSPIRE SUCCESS. Jack Stark, president at Continental, the recalibration driven by the commodity price — NORTH DAKOTA nosedive lives on. “The Bakken just keeps GOVERNOR D D OUG BURGUM getting better, better than ever,” says Stark, calling the Williston Basin “America’s then an acceleration after that. Helms esti- quality oil play.” For Stark, the storyline on the Bakken mates that $127 billion has been invested in North Dakota Dako ta oil and gas since sin ce early earl y in the is consistent and just keeps getting better, 20th Century. And he adds that Bakken well chalking it up to what he calls the “tenacity productivity tops the nation. and ingenuity “ of the industry, considerA long-time player in North Dakota’s oil/ ing the pressures applied from the falling gas patch, which now stands as the nation’s global prices in recent years. Stark sees second biggest oil producer, Helms sat back “step-changes” in recent months and years in and grinned for much of the final morning the Bakken, spurred from within among the program at the WBPC confab, listening various operating companies that have held to industry executives, CEOs and others, and expanded their acreage in the play. Stark predict great things for the Bakken, which speaks as the head of the top leaseholder and Helms described as only being in the end producer in the Bakken. Sixty percent of of the first quarter as far as its full potential Continental’s capital investments for 2018 is concerned. Three-quarters of the play’s were slated for the Bakken ($1.2 billion). shelf life is still ahead. Amid the growing success that is overHelms speaks in superlatives when it hyped, according to some skeptics, all the comes to the Bakken potential for growth, operators appear to be benefitting from but he is realistic about the fact that its what Stark and others see as native intuition current adequate takeaway capacity will and hard work. “The rock hasn’t changed” soon be full, and the state and industry at he reminds his audience. “This all happened this point are behind schedule for planning, through technology; it is what you do with permitting and building all the infrastruc- the rock that makes the difference, interconture that will be needed. There is at least $3 necting with it, if you will. That is what has

manifested in step-changes in performance [doubling of returns-per-av returns-per-average-well erage-well 2017 to 2018].” For Continental, one of the operating changes involves using more perforations/ feet of pipe in fracking jobs, Stark points out. Along with the increased volumes of proppant, density of perforation – one every 10 yards rather than one every 60 yards – has been a game-changer for Stark. As a result, Continental’s recovery factors are off the charts, jumping from 3%-5% to 15%-20% of the oil in place, according to company statistics. “That’s a huge number; the ‘size of the prize’ is huge here,” he says. “We’re doing a much better job of stimulating the rock,” Stark says. On a more macro basis, what the crews for all the operators are doing is taking the Bakken “to a whole new level,” he says. “It is happening across all of the companies.” To underscore his point, Stark displays a chart showing an array of new wells that have produced in excess of 100,000 bbls their first 90 days. “It is tending to push the economics up across the whole basin,” Stark says. Stark deconstructs Bakken crude oil in comparison to the Permian Basin in west

Texas and southeast New Mexico. There is a much higher gas proportion among the Permian oil volumes than in the Bakken, says Stark, reminding his audience that the Bakken is the most oil-rich play in the United States. The Bakken average oil pro portion is 52%, while in the Permian the oil proportion is about 32%, Stark says. “The Bakken is just a lower cost barrel to produce, compared to the Permian,” he says, adding that the Bakken production is much more similar in its quality of composition, and that makes it very attractive to refiners internationally,, particularly in Europe. internationally “At Continental we expect 2018 to be a breakout year, year, and we think that will be true for the Bakken overall,” Stark says. Sharing Stark’s bullishness on the Bakken were a host of other CEOs and executives outlining their thoughts on what several called a “transformation and resurgence” that has been fueled by technology breakthroughs involving pipeline scanning and use of drones that prompted some to label the Bakken as the “digital oilfield.” This is exemplified by a global giant like Caterpillar which has more than 15,000 pieces of oil/gas equipment worldwide,

and all of them are being equipped with electronic monitoring and controls aimed at having smarter, better operating machines, many of which are monitored remotely around the globe. Saying there is no doubt that the United States has achieved energy inde pendence, Marathon Oil Corp. executive Mike Henderson singles out technology as playing a significant role in the resurgence of the Bakken, which in the eyes of Marathon’s executive team has become the “benchmark” for America’s “high-tech shale oilfield.” He classified the Bakken as “evolving” and one of the top unconventional basins in the United States, competing at a very high level. After pulling back its activity in the Bakken in 2014-16, Marathon has come back with the attitude that it will “never be satisfied with the status quo,” says Henderson, vice president for reserve plays in Oklahoma and North Dakota. When the company was “downshifting” in the Bakken, its operating teams became much more focused on creating new ways to improve their approach to the business. As a result, Henderson says they found new

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ways to maximize well productivity that are paying big dividends in 2018. Having produced more than 100 million bbls over the years in the Bakken, Marathon at one point of the price depression went down to one rig in 2015-16, and Henderson says “that is when the story got interesting for us.” He says the company’s Bakken teams really pushed the envelope, creating some of the “best-in-basin” new wells in the Bakken last year and in 2018. In the midst of several thousand industry attendees at the WBPC, Henderson laid our Marathon’s recipe for success that has exemplified the past two years. He called out subsurface understanding, data sets, and modeling as keys for the swing upward in well productivity and profitability. “Quite often we get asked what is the ‘secret sauce’, and I can tell anyone that it is two parts people [individual and team innovativeness] and one part technology,” says Henderson, adding that in the recent down years he has witnessed the coming together of people and technology. Important to the people part of the equation is culture, Henderson opines, stressing the need for a culture that encourages and

allows people to take ownership. Without this internal environment, companies will never realize the full potential of new technology. “[Marathon’s] Bakken team pushed to the limits and did not hesitate to explore new dimensions. That’s our secret sauce.” New technology and the smart application of it are essential for operators like Marathon to move forward, Henderson says. Workers have to think differently and act differently to make the right moves for achieving better results. “That is the driver of better performance,” he says. “We have to take advantage of the link between technology and operational excellence.” Marathon has focused its innovation on subsurface work because that is what makes the E&P sector so unique and challenging. But Henderson makes the case for putting equal amounts of focus on data sets and their better use. “We can answer the critical questions with the data we have today, but we need to look at that data differently; we don’t suffer from a lack of data, so it is more a question of how we take all of this data and do something different with it.” Other industries from health care to the Internet have already figured out how to

manipulate their data sets, and the oil/gas industry needs to do the same, Henderson says. “We can use this data, coupled with science and physics and be much more accurate and efficient in finding and producing oil and natural gas,” he says. The future of the industry lies in the digital oilfield, which Marathon and other operators are already experiencing. Marathon’s control center in the Bakken sports dashboards and specialized data that allow operators to quickly interpret masses of information, according to Henderson. “This real-time data is only as good as your ability to tackle it,” he says. ConocoPhillips’ Erec Isaacson, vice president for the Rockies business unit, agrees that the industry has made considerable progress despite low commodity prices in technology, innovation and optimization, and this includes the effective use of what he calls “big data analytics.” For Isaacson, interpreting and applying these analytics have become somewhat routine in the industry. “It was just a talking point two or three years ago.” He says the use of innovation and efficiencies has make $65/bbl oil the equivalent of $100/bbl oil in today’s environ-

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ment where industry wide efficiencies have slashed production costs by 35%. With the efficiencies now in place, one rig is the equivalent of three rigs just a few years ago. Isaacson’s one caveat, however, is “don’t let up, keep innovating” because the world is still oversupplied with oil in 2018. The fact that North Dakota’s somewhat remote pot of black gold is ever-more connected to the global oil/gas markets is both encouraging and daunting, and the many executives and engineers who helped deconstruct the Bakken at the three-day WBPC were bullish butt not bra bu brash sh.. They They temp tempere ered d their their enth enthus usias iasm m with doses of reality as well. They laid out various recipes of success, all of which embody the concept of a digital oilfield. For the Bakken, Whiting Petroleum Corp. CEO Brad Holly, a veteran in the E&P world who joined Whiting within the past 12 months, stated one of the advantages of the North Nort h Dakota Dakota play play was was “regu “regulato latory ry certai certainty” nty” that he sees as provided by state and local officials who have created what Holly calls “a very cooperative environment with sensible rules.” Innovation and technology can make a greater difference in such an environment, he and other speakers emphasize. Over at one of the major long-time operators in the Bakken, Houston-based Oasis Petroleum Corp. CEO Tom Nusz says his firm’s 15-year history of drilling in the Bakken from its emergence as a major U.S. shale play has helped it thrive even during some of the worst months of the recent price crash. Today it has carved out service and midstream units, taking the latter publi pu blicc in in 2017 2017 as Oa Oasis sis bec becam amee the the fou fourth rth lar larggest producer in the Bakken. Oasis remained free-cash flow positive during the commodity price downturn, hedging much of its production in 2014-15, Nusz says. While it was protecting its balance sheet, its operators were slashing well costs by 30% and i ncreasing well recoveries up to 50% or more, he says. Costs for finding new supplies are 50% less and recovery margins are what Nusz calls “very attractive.” He says Oasis has about 15 years of supply in the Bakken core, and up to 30 years in the noncore acreage. “Since the downturn, what we have seen is a lot of activity outside the core with some pretty intere interesting sting result results,” s,” says Nusz Nusz,, predictpredicting that both oil and gas volumes are going to grow significantly in the future. And this equates to expansion for Oasis Midstream Partners, which is building a lot of gas processing and pipelines in the Bakken. All in all, oil and gas veterans are exhibiting a renewed confidence based on the recognition that technology and innovation now define the oilfields of the nation. And just about anything anything is thought thought to be possible possible in 2018 and beyond. The stakes and the possibilities are high. P&GJ

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Howell

New Day for Pipeline Tolls

By David Howell, Pipeline Equities, Houston

I

t used to be simple. A company decided to build a pipeline. They hired a rightof-way agent, secured easements at predictable rates, rates, and the the project began. began.

closely acquainted with the going rate/historical rate paid for rights-of-way. However, these old rates no longer apply, as more enlightened landowners are rejecting the old assumptions and are demanding and getting more lucrative contracts.

Few Challenges

other products to a suburban refinery district The city was charging annual fees up to 2% of the value of the product in the pipeline, which generated $16 million to $25 million per year, but he wanted to stabilize this income (at the higher amount) and asked if an appraisal of the lines was needed. We were in the process of determining the scope of work when he called back to report the California Supreme Court had set a precedent with its ruling in another case, which would allow the city could charge up to 10% of the value of the product.

Most landowners have small tracts of a few hundred feet and don’t have the resources or inclination to fight or challenge a condemnation suit. Generally, they accept what pipeline companies offer, which has been very generous in many cases. Those offers increased, in part, due to the failure of many condemnation suits Length of Pipe Houston has always been a pro-business and the length of time it takes to respond Ten lines crossing a channel. and receive a judgment. In the end, delay- town. It was a land developer’s city and In those days, routes were determined, ing a project for a condemnation suit can continues as an entrepreneurial hot spot. The Houston Ship Channel connects inland c ostly. engineering was done, and the land be costly. Right-of-way costs still hover at about Houston to the Gulf of Mexico 60 miles acquired. The pipeline company controlled all of these facets, except for land 5-10% of the overall cost of the pipeline away. There are many refineries, as well as a nd factories, facto ries, along alon g the way that use acquisition. Landowners would be paid proj ect, and it does n’t beho ove a pipe - plants and the going rate for right-of-way in the line owner to delay things over a minor oil and oil-derived products to build and area based on standard or historic meth- cost problem on some easements. The maintain thousands of products. Pipelines easement cost on the project as a whole crisscross the channel all along the route. ods and amounts. The fees charged by the Port Authority If an appraisal was required, then a seems negligible, but some agents persist and the Houston Ship Channel to cross their in th threats reats of condemnation, perhaps in reliable and economic approach was the jurisdictions are based on the diameter and across-the-fence (ATF) method, which an effort to prevent a domino effect from length of the pipe. For example, an 8- to determined the property value based on landowners. 16-inch line would have a fee of $4.46 whatever the property next door was Navajo Royalties per linear foot, with an $1,831 minimum worth. If not the ATF method, then the The first unusual easement valuation assessment per line. A 32- to 48-inch line going historic rate would be the determinhappened several years ago in a court case would be assessed at $14.23 per foot, with ing factor. If things got sticky or time conin which a pipeline company was sued by a $5,802 minimum per line, and so forth. suming in negotiating with the landowner the Navajos of Arizona, who sought an in question, the agent could always play a annual royalty or fee based on a percentage Based on Volume condemnation card and threaten to evoke of the value of the product being transported Last year, while preparing for a sizable an eminent domain seizure. water pipeline project p roject in West Texas, Texas, a comthrough the line. The case was settled out of Then the Information Age came along court and, as is usually the case, c ase, the terms of pany leased an easement across University and disrupted things. Previously, the best their agreement were not disclosed. Lands. The University Land Trust (UT way to find out what was happening with At first, this seemed to be a potential situ- Lands) owns about 3 million acres in West other landowners was to visit the local Dairy ation due to the sovereignty of the Navajo Texas. Its job is to generate as much cash Queen. Suddenly, everyone’s information Nation, but the number of cases like this flow as possible, and its procedure is well was instantly available on the Internet. In one have increased where sovereignty was known in the right-of-way business. many cases of purchasing easements, the not a factor. UT Lands’ standard price for 10-year going rate from pipeline companies is no easement is based on pipe diameter and a longer relevant to the landowner. The rate Fee-Based on Value damage fee when taken it up in 10 years, in the landowner’s mind is calculated in a Last fall, the asset manager for the city of unless the easement lease is renewed for different manner. Los Angeles called to ask about appraising an additional 10 y ears. A surprise occurred Our company, Pipeline Equities, has the pipelines that were permitted by fee and last year when the Trust decided to assess a bought and paid damages on millions millions of feet contract to run under the streets of the city. new pipeline based on volume of throughof easement while installing and removing There were 23 lines of various lengths put at $.10 per barrel barrel,, in additi addition on to the pipeline over the past 30 years. We are carrying crude oil, jet fuel, gasoline and easement cost. 28

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With a capacity of 250,000 bpd, that rate would flow $25,000 per day into university coffers to help to educate students. So, the company was left with either incorporating the cost into their cost of operations or raising its tariffs.

their channel. The company is not sure it wants the pipelines crossing the channel at any rate and is assessing its position in that regard. But, the pipeline has no other place to go, as the Arbitrary Basis same company owns most In effect, almost all assessments are arbisurrounding properties. Is trary in nature. It’s doubtful there was any Pipelines crossing public drainage system. this a case for condemnaformula 150 years ago when someone paid tion? The considerations of $267 million to go an alternate route, after $.15 per rod for the first pipeline easement. 21 crude and product pipeline crossing environmental considerations. The city of Houston owns some property While the cases cited in this article were on the east side of the city and assessed over a channel that empties into the Pacific Ocean 2 miles away are huge. initially surprising, it’s clear that a trend of a fee of $28,000 per year for one line to landowners determining the easement value What formula would determine the risk cross the property. There was no mention has begun. This trend is limited, however, to pipeline owners in cases of vandalism, of the outside diameter or overall length of deterioration or accidental rupture? What to those with the resources and knowledge the pipeline. A land developer in Los Angeles County, amount is sufficient to mitigate risks and to challenge rather than accept the going rates offered by pipeline companies. Calif., ceded the surface rights to the flood award adequate and just compensation? Still, with so much information readily A pipeline company in the Marcellus control district for a drainage channel, but available to those willing to do the research, continues to own the land below the channel Shale determined it could save significant for many that day is already here. P&GJ time and expense by purchasing the rights and the air rights above it. Over the past 50 years, the land company to lay a pipeline on the property owned Author: David Howell leads Pipeline road d auth orit y over a 200 200-mil -milee Equities in pipeline remova removals ls and acquisihas given permits for various pipelines to by a toll roa cross the property and currently receives an route. The cost of the transaction: a $178 tions in Oklahoma, Louisiana, Texas New average of $5,600 per year, per line to cross million fee paid to the toll road owners vs. Mexico and California.

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Designing of Skin Effect Current Traced Cross-Country Pipelines By Tittu Alagu and Koya Venkata Reddy, FACT Engineering and Design Organization, Kerala, India

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rowing energy demand, coupled with the availability of sour and heavy crude, and the more conscious environmental regulations are driving refineries across the globe to enhance their facilities to process sour and heavy crude, and produce higher value middle distillates and end products. This spurs demand for greater storage capacity for crude, as well as petroleum products handling terminals and the need for transportation of high viscous crude, high pour fuel oils and molten sulfur in liquid form. With this comes the necessity of heat tracing system. The term heat-tracing refers to the continuous or intermittent application of heat to a pipeline or vessel in order to replace heat loss.1 Two common uses of heat tracing are preventing water pipes from freezing and maintaining fuel oil pipes at high enough temperatures that the viscosity of the fuel oil will allow easy pumping. Industrial heat tracing are of two types, fluidand electricity-based heat tracing systems: Fluid-tracing involves strapping a small 38 / to ½-inch pipe or tube called a tracer to the pipeline pipeli ne or vesse vessell to be traced and cover covered ed by therma thermall insula insulation. tion. The tracer pipe will be supplied supplied with a hot fluid, which transfers transfers its heat to the main pipeline or vessel by conduction. Steam is by far the most common and preferred choice of tracing fluid used in chemical process industry for its high

heat content, availability at low cost from the waste heat recovery boilers and being relatively safe compared to electric tracing. Electric-tracing involves strapping an electric heating cable to the pipeline or vessel to be traced and cover by thermal insulation. The supply of electricity to the heating cable will generate heat, which will be transferred to the main pipeline or vessel by conduction. The majority of commercial electric-tracing systems use the resistive type heater, wherein the heat is produced in proportion to the square of the current (I) and the resistance (R) of the elements (I2R). Other specialized electric tracing systems make use of impedance, induction, and skin conduction effects to generate and transfer heat.

Cross-Country Pipel Pipelines ines Cross-country pipelines play a pivotal role in the effective management of the energy resources around the globe. It has been recognized as the most efficient, safe and eco-friendly mode of transportation of petroleum products and crude oil from one place to another. another. Two probable scenarios in cross country pipelines in which heat tracing will be the only viable option: � Pumping of waxy crude and high-pour petroleum petrole um products: products: As the waxy waxy crude flows through a cold pipe (with a wall temperature below the cloud point of the crude) crystals of wax may be

formed on the wall. As the wax thickness increases, pressure-drop across the pipe incre increases ases and the pumpin pumping g pressure needs to be increased to maintain a constant flow rate. As a result, the power requirement requirement for crude transport transport will increase over a period of time. Further the pipeline may require frequent flushing/pigging in order to avoid choked condition. This becomes a real setback in the case of cross country pipelines pipelin es in which pumpin pumping/ene g/energy rgy cost is relatively high, in addition to the risk of pipeline getting blocked completely. � Pumping of molten sulfur via pipeline: Refining of crude oil and treatment of natural gas yields considerable amounts of sulfur. The extracted liquid sulfur is pelletized pelleti zed and and transporte transported d by road road vehivehicle, rail or water. This sulfur, on reaching its destination, has to be re-melted for further processing. The whole process incurs considerable energy cost besides, besid es, the cost of hand handling ling and storage of solid sulfur, which has its own drawbacks. And that is how pumping of molten sulfur via pipeline provided with heat tracing is considered to be economically viable alternate. Generally, for tracing long or multiple pipe runs electric tracing is preferred over steam tracing, as steam tracing will be relatively more expensive to install and maintain. The periodic leaks and failed steam traps in a steam-traced system waste energy and demand additional labor costs for repair and replacement. Also, the electric tracing systems provide better temperature control and much more efficient utilization of energy than that of steam.

Types of Electric Tracing Electric trace heating cable can be divided into four distinct product classifications: � Series circuit, mineral insulated (mi) cables (constant watt output) � Parallel circuit heating cables (constant watt output) � Self-regulating heating cables (variable watt output)

Skin effect heating Figure 1: Typical steam tracing system

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Each type caters to specific application and has its own advantages and disadvan-

tages. A comparison of these electric heat tracing methods is available in the pipeline and piping book.

Skin Effect Current Tracing Principle of operation – Skin-effect tracing system (STS)/skin-effect current tracing (SECT) is based on proximity effect, whereby heat is generated on the inner surface of a ferromagnetic heat tube that is thermally coupled (welded) to the pipe to be heat traced. A non-magnetic conductor material (copper or aluminum) is placed inside the heat tube and connected to the tube at the far end. The tube and conductor are then connected to an AC voltage source in a series connection. When the voltage is applied in this manner, the current flows in one direction and returns through the steel tube in the opposite direction. The full current flows in inner surface of the steel tube and in its outer surface is virtually absent. This method of heating is called skin-effect heating because the return path of the circuit current is pulled to the inner surface (approximately 1 mm) of the heat tube by both the skin and the proximity effect between betwe en the heat heat tube and and the conduct conductor or.. Components – The SECT system consist of the following components: 1. Heat/tracing tube 2. Heating cable/wire 3. Pull box/splice box for cable cable pulling inside the tracing tube 4. Power feed box for connecting the power supply 5. Termination box 6. Temperature sensors. 7. Control panel for controlling the heating 8. Custom built transformer for powering the system Control operation – The electrical controls for the skin effect current tracing system are designed to provide the desired control of the heating system as well as provide functional indications. The system is provided with automatic and manual control modes. The manual mode is intended for use only during start up, maintenance checks and trou blesho ble shootin oting g of the ele electri ctrical cal sys system tem.. Whe When n using the manual control mode, care must be taken to continuou continuously sly monitor monitor the sys system tem operation. In manual mode, the temperature controller is bypassed and the system will continue to heat as long as the manual mode is maintained. The temperature indicator and alarms are active in the manual mode. The automatic mode provides closed loop temperature control and indication. The pipe temperature sensor provides a continuous signal to the indicating temperature controller. The temperature controller compares this signal to the reference signal (set point temperature). When the pipe tem perature is above the set point, the system

Figure 2: A 2: A typical electric tracing systems

will be “off.” When the pipe temperature is below the set point, the system will be “on.” The temperature controller has low temperature and high temperature alarm contacts. Skin effect current tracing for pipelines – Skin effect heat tracing system is found most suitable for cross country pipe lines as per the feature listed below: 1. Most economical method for extremely long pipe lengths (up to 25 km) can be traced with a single electric supply point. 2. Because of the welded contact between the tube and the pipe, higher heat transfer rates are attained. 3. Because of the skin and proximity effect, the outer surface of heat-producing element (heat tube) has zero potential to ground. The tube is earthed and there are no electrical potentials, which make the system safe for maintenance staff. Applications – SECT system is widely applied in transporting crude, petroleum products produ cts and molten sulfur. sulfur. Its appli application cationss also include storage tank foundation heating to prevent frost heave formation and subsea pipelines. pipeli nes. Refer References ences of applicat application ion of of SECT SECT in cross-country pipelines are given below:

1. 700-km, 24-inch, 24-in ch, underground crude oil pipeline of Cairn India Limited from Mangala Processing Terminal, Barmer, Rajasthan to Salaya Terminal, Gujarat.5(2010) 2. 35-km, 12-inch, above-ground dual sulfur pipeline to transfer molten sulfur from 11 producers to a sulfur pelletizer facility, Ras Laffan, Qatar5. (2009) However the application of SECT system has its own limitations, they are: � Involve considerable custom design � Do not lend easily to the production of uniform heating, and IEEE rates the method as providing only moderate system efficiency � Installations cannot be modified, and the complete system fails with a single line break � Skin effect heat-tracing is generally not cost-effective for pipelines shorter than 1.6 km � Not practical for non-metallic or com plex piping Capitalized cost or life time cost of pipeline: The design of a heat traced crosscountry pipeline involves calculation of the

Figure 3: Skin 3: Skin effect current tracing system components.

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economic pipeline size. The most economical pipeline size is arrived at by comparing the lifetime cost of two or more pipeline sizes, considering the pipeline size, which provides provid es the least lifetime cost. cost. The lifetime cost involves computation of capitalized cost of pipeline, heat tracing system and electricity for pumping and pipeline temperature maintenance over its useful service life. The following are the stepwise procedures to compute the lifetime cost of the pipeline: 1. Choose Choose a line size – Calculate pressure drop and ascertain the pumping power requirement 2. Estimate the pipeline investment cost 3. Choose a heat tracing t racing system (skin effect current tracing) 4. Calculate the maximum heat loss across the pipeline and ascertain the power requirement 5. Define the no. of heat tubes required and the power feeding and distribution system 6. Estimate the investment cost of the heat tracing system 7. Estimate the lifetime cost of the entire system Repeat the procedures by choosing choosing different line sizes and compare the com puted lifetime cost of all line sizes sizes chosen chosen to arrive at the economic pipeline size: Surge analysis of the proposed system is to be carried out to find the maximum surge pressure developed in the system. A surge relief system shall be installed, if required to protect the pipeline or the pipeline is designed for the maximum surge pressure. The constructability of the pipeline along the right-of-way (ROW) minimizing the obstruction/hindrance obstruction/hindra nce to traffic and public is planned. The above-ground above-ground or underground portions are to be clearly demarcated. In case of power failure, the pipeline temperature tends to decrease and to avoid congealing in case of petroleum products and low tem pera pe ratu ture re solid solidif ifyi ying ng subs substa tanc nces es,, flushi flushing ng of the pipe pi peli line ne wi with th a pro prope perr liq liqui uid d is is to to be be car carrie ried d out out.. However,, calculations are to be performed to see However that temperature drop in the pipeline is minimal

and while flushing the line average bulk temperature inside the pipeline fluid doesn’t drop below the solidification point of the mixture of the flushing fluid and original fluid in the pipeline. The skin effect system operates as series resistance circuit having a single-phase power source. The source of power can be either from one or both ends or from middle of the pipeline depending upon the length of pipeline and effective use of power system. Each heat tube has got the capacity to impart certain heat to the main pipe. According to the heat loss calculations, the required no of heat tubes are calculated. Total or 50% redundancy is provided for heat tubes to take care of the malfunctioning of heat tube circuit. The redundancy comes at a cost but makes the system more reliable. The consequences of power failure and mitigation measures of it’s effects is to be clearly thought off at the time ti me of basic design as prolonged power supply failure will defeat the purpose of heat tracing. Product solidification inside the pipeline will make the whole design intention defeated.

Other Design Aspects

1. Hazardous area classification – All electric components and instruments used in the SECT system have to comply with the Hazardous Area Classification of the product being handled. 2. Optical fiber-based temperature monitoring system – Provides continuous monitoring of the temperature profile of the pipeline and helps to find any cold spots. In addition, fiber-optic monitoring facilitates the measurement of average temperatures at 1-meter intervals over the length of the fiber along the entire length of the pipeline. This substantially reduces the potential effect of localized temperature variations in the pipeline. Fiber-optic temperature monitoring has particular partic ular adva advantage ntagess over thermi thermister ster and thermocouple-based systems, as fiber-optic systems are very robust and unaffected by electrical noise. Figure 4 shows the back-scattered light spectrum for distributed temperature measurement, a pulse 0-os Pulses of light laser is coupled to an optical fiber through a directionLaser al coupler. 3. Current protectio prote ction n syste system m Incident Back-Scattered Light Raleigh – Over-curr Over-current ent or Brillouin Light differential current protection may be Analyzer Stokes provided prov ided on the Raman Band Antistokes skin effect current Raman tracing system. Band Over-current protection senses a current above cold Wavelength starting current. If Figure 4: Typical 4: Typical back-scattered light spectrum for distributed temperathe skin effect curture measurement.

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rent tracing system current rises to the set value, the system will shut down and resetting of the system is required to restart. Differential current protection senses the difference in current of two sections. If the current in one section rises over or falls below the other section, annunciation and system shut down will occur. After the cause of shut down is found and repaired, manually reset to “start” the system heating. 4. Cathodic protection – Normally SECT based bas ed pip pipelin elinee will hav havee PUF insu insulalation for heat conservation of the fluid wrapped inside the HDPE jacket for preventing any chance of water ingress and there by protects the pipe line from corrosion under insulation. Hence cathodic protect pro tection ion is not required required for cor corrosi rosion on control. However, all carrier pipes and heat tubes shall be sand blasted to a surface finish of SA 2.5 and applied with high build epoxy paint of 400 microns suitable for 1,500 degree C as an additional protection to avoid corrosion. Since the pipeline systems have zero potenti pot ential, al, skin eff effect ect hea heatt trac tracing ing will have no effect on the cathodic protection of the adjacent lines. EFERENCES R EFERENCES K. Henry, Introduction to Heat Tracing, Cold Regions Research and Engineering Lab, Report no. CRRELTD-86-1, June 1986, p. 1.

Perry’s Chemical Engineers’ Handbook, Eighth Edition, Section 10, Process Plant Piping, p. 10-135, Heat Tracing Of Piping Systems. Fluid Heat Tracing, Steam by Chet Sandberg, P.E., Joseph T. T. Lonsdale, & J. Erickson, P.E., P.E., Chapter B6 Heat-Tracing Of Piping Systems, p. B.242.

Authors: Author s: Titt Tittu u Alag Alagu u is assistant process manager working in FACT Engi En gine neer erin ing g an and d De Desi sign gn Organ-isation, Cochin, Kera Ke rala la,, In Indi dia. a. He ha hass eight years experience in process engineering and has specialization in Process simulation. Tittu graduated in with a bachelor’s bachelor’s degree degree in Petr Pe troc oche hemi mica call Eng Engin inee eeri ring ng fr from om Bh Bhar arat athi hida dasa san n University, Trichy, Tamil Nadu, India. Koya Venka enkata ta Reddy Red dy is assistant general manager, process engineering, at FACT Engi En gine neer erin ing g & De Desi sign gn Organization (FEDO), a division of Fertilizers and Chemicals Travancore Ltd. He has 26 years of experience in chemical plant operations. Reddy holds a bachelor’s of technology degree from Andhra University (Visakhapatnam) and a master’s of technology degree in project management from Cochin University of Science and Technology.

PGJ Exclusive

Fugate

Mobile Technology Takes Pipeline Data to the Cloud

By Lance Fugate, Vice President of Operations, Enmapp Pipeline Data

O

ne of the biggest challenges facing the construction of pipeline proj ects is that they opera operate te in a dynamic, complex environment where external bottlenecks and stakeholders can introduce excessive delays and costs. To meet those changes, contractors and pipeline managers are increasingly being bein g asked for data d ata to t o support supp ort r egula tory compliance, cost management, safety and maintenance objectives — the meat and potatoes pota toes of the indu industry. stry. Such data is fast becoming what Forbes magazine called “the oil of the digital era” — there th ere to be b e used use d in i n new ways to generg enerate products and services in fast-growing markets that can be only peripherally aligned with pipeline building itself. Increased information offers new ways to evaluate contractors, determine the advantage one pipeline route over another, or provide metrics to monitor the pipeline pipe line const construct ruct ion itse itself. lf. For decades, collecting, evaluating and maintaining data has been done with oldschool surveying devices, pencil-and paper, cumbe cumbersom rsomee and erro error-gen r-generat erating ing transcription techniques and space-eating storage facilities. The process makes data acquisition expensive. But does it have to be? Thanks to smart phones, table tablets ts and the cloud, some pipeline services companies are saying that the answer is “no.” They are using applications that leverage a Global Network Services Solution (GNSS) receiver tethered by Bluetooth to a smartphone, which enables the collection of sub-meter accurate pipeline data in the field to automatically update databases over-the-air. Taking this field data concept a step further, Enmapp built a mobile application using a platform called TerraGo Magic. This approach allows customization of field data collection software for customers without writing a single line of code. This platform allows apps to be designed that are tailored to a customer, a pipeline or 34

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even a project. All the forms, reports and workflows can be built without the time or expense of software development and without the limitations of a commercial data collector app. The customer gets a data package with all the information, fields, photos and videos needed. The data package is transmitted digitally to the cloud or directly to headquarters. There data can be analyzed and evaluated, used to monitor construction progress prog ress or main maintena tenance nce needs needs,, extr extracte acted d for regulatory reports.

PROGRESSIVE

PIPELINE

SERVICES COMPANIES SHOULD VIEW THEIR VALUE AS BEING ENHANCED BY DIGITAL TRANSFORMATION PROGRAMS , NOT LESSENED BY THEM .

G OING

DIGITAL ALLOWS A

COMPANY TO LEVERAGE ITS EXPERTISE AND UNLOCK GREATER VALUE WITH TRACEABLE , VERIFIABLE AND INTELLIGENT DATA ANALYTICS .

Responsibility for welds, status and incident reports, and quality and performance evaluation metrics can be integrated into a narrative as the pipeline is built. buil t. Repai Repairr rate ratess on welds and othe otherr inspectors’ findings can be woven into that narrative in real time, with trends established and addressed before their damage is compounded. If there is an issue – a faulty weld, a pipeline fissure that becomes an oil leak – responsibility can be tracked. Quality evaluations are quantified, and regulatory bodies’ queries can be addressed addressed with easily easily retrievable digital facts, not buried paper paper.. Data becomes Big Data, collected with

smartphones or tablet computers to keep costs down – turning pen-and-paper techniques into the dinosaurs that formed the petroleum petro leum in the first place. Constr uctio uction n can be monitored in real or near real-time, and mistakes can be remedied as they occur. Duplicated effort, often an issue on long pipeline projects, is eliminated beforee it can occur. Decisi ons can be befor made quickly. Downtime can be reduced or eliminated completely. So can the expense of dispatching crews to re- survey areas in which data is incomplete. The customer – in this case, the pipeline contractor and those who keep watchful eyes over it – gains some control over the cost of this data acquisition, as well as what can be done with its products. Return on investment can be measured quickly. Other stakeholders, such as government regulatory agencies and certified weld and coding inspectors, many of which also use old-fashioned methods to do their jobs, can be part of the digital migration, gaining speed and cutting expense in checking data and analyzing reports. Risk management firms can enjoy those same advantages, determining and monitoring their exposure as it evolves. Environmentalists gain new metrics in ascertaining impact on nature. Also of note, field workers do much of the heavy lifting in collecting the data with smartphones or tablet computers, becoming becom ing empower em power ed when t hey add d ata collection to their resumes. So what’s holding back the customized field data collection software revolution? In essence, there are a handful of issues to overcome: � The pipeline industry’s reluctance to embrace new methods in favor of legacy procedures. Part of that reluctance is an unwillingness to change what has been demonstrated to work “good enough.” Another par t is the fe fear ar of new te techn chnol ology. ogy. Ironically, that fear isn’t shared by th thee fi fiel eld d for ce, whi ch by and large is comfortable with new

smartphone- and tablet-based tools. Bringing in a consultant to smooth over transition to new technol ogy is a way of coping. � The industry is wary of investing in the IT infrastructure. The reality of digital data collection is that companies traditionally had to invest in an enterprise Geographic Information System (GIS) to server as the backend platform, as well as GIS consultants to build custom solutions and GIS experts to manage it over time. With cloud-based mobile applications, there is no infrastructure and a developer isn’t needed to customize the applications. � There is a reluctance among many pip eli eline ne ser vic vices es com compan panies ies to dis turb the status quo. They see ceding data collection to customers as cutting their business’ throats. Other companies, though, see the inevitability of digital data collection as part of the future of pipeline construction, and are modifying business models to embrace it. Progressive pipeline services compa-

nies should view their value as being Picture all the trucks on all the routes enhanced by digital transformation proof all those projects, with four out of five grams, not lessened by them. Going filling out three-part forms by hand to build digital allows a company to leverage its the mountain of paper to satisfy all of those expertise and unlock greater value with customers. The figure, by the way, accutraceable, verifiable and intelligent data rately describes the number of companies analytics. still doing old school data collection. Then By using mobile apps like Enmapp add all the back office time involved in tranPipeline we have seen both the clear scription and data entry of all those forms. reduction of customer data collection And, of course, the thousands of illegible costs and the dramatic increase in data fields needing to be re-entered, along with the value. And unlike “old school” methods, data errors that require countless repeat visits digital field data collection is scalable for and inspections. Then, the printing of volumes the most challenging projects. of reports to satisfy stakeholders in all the As an example of the need for digital agencies, businesses and communities. Now ins tea d, pic tur e all th thee wor kdata collection, consider that over $20 bil lio n wor th of pi pipel pel ine pro jec ts ts,, in ers at the construction sites capturing various stages of planning, all of which pho tos and for ms wit with h a tap on the their ir will use multiple prime contractors with smart phones, instantly available for ondiverse data collection and quality man- demand reports by any stakeholder. agement systems and impact hundreds of The mobile digital revolution has arrived, will be effecting extremely diverse and and the time for the oil pipeline industry to sensitive environmental areas. A host of join it has come. Game-ch Game-changing anging tools are risk management stakeholders have a lot there. So is the workforce with the skills to at stake in these projects and are going use it. All that remains is for our industry to want data-filled reports that address to let go of its paper past and embrace a better, digita digitall future. fu ture. P&GJ concerns with hard facts.

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Northeast Looking at Record Natural Gas Pipeline Buildout in 2018 By Katie Dyl and Jim O’Sullivan, U.S. Energy Information Administration

T

he U.S. Energy Information Administration (EIA) expects construction of new natural gas pipeline capacity in the United States to continue in 2018, in particular in the northeastern United States. By the end of 2018, if all projects come online by their scheduled service dates, more than 23 Bcf/d of takeaway capacity will be online out of the Northeast, up from an estimated 16.7 Bcf/d at the end of 2017 and more than three times the takeaway capacity at the end of 2014. The growth of natural gas production in the Marcellus and Utica basins in Pennsylvania, Ohio and West Virginia is constrained by the lack of available takeaway pipeline capacity to move it to new markets. As new pipeline projects come online, they will create an outlet for increased production, providing natural gas to demand markets in the Midwest, the Southeast, eastern Canada, and the Gulf Coast. Currently, no major pipeline capacity expansions in advanced development are slated to come online in New England because of stakeholder concerns raised in the development process. Of the projects scheduled to be in service by the end of 2018, most are associated with four major interstate pipelines: Columbia Pipeline Group (TCO), which includes both Columbia Gas and Columbia Gulf Transmission; Transcontinental Gas Pipeline (Transco); Rover Pipeline; and

NEXUS Pipe Pipelin line. e. The Columbia Pipeline Group (TCO) has two expansion projects intended to add 4.2 Bcf/d of takeaway capacity out of the Northeast: Leach Xpress and Mountaineer Xpress. The Leach Xpress projec pro ject, t, whi which ch ent entere ered d ser servic vic e on Jan 1, supplies an additional 1.5 Bcf/d of capacity out of West Virginia and Ohio, and the Mountaineer Xpress project, which is scheduled to enter service in late 2018, will increase takeaway out of West Virginia by an additional 2.7 Bcf/d. As much as 2 Bcf/d of the natural gas from these two pipelines can be sent directly to the Gulf Coast via expansion projects on TCO’s Columbia Gulf pipe line , and the rema remaind inder er will ente r the TCO pool in Boyd County, Ky. Another TCO expansion project, the WB Xpress proj ect, will incr ease main mainlin linee capa city to both the east (500 MMcf/d) and west (800 MMcf/d) when it is completed in late 2018. Three projects associated with the Transcontinental Gas Pipeline are intended to add more than 3 Bcf/d o f capacity out of Pennsylvania and West Virginia: Atlantic Sunrise, Mountain Valley Pipeline, and Equitrans Expansion. Atlantic Sunrise, the first phase of which was completed in 2017, is a nearly $3 billion project that will providee 1.7 provid 1. 7 Bcf/d Bc f/d of bidirec b idirectional tional capaci capacity ty on the Transco System. The Mountain Valley Pipeline (2 Bcf/d), a new pipeline from West Virginia to

the Transco system in southern Virginia, and the Equitrans Expansion Project (0.600000 MMcF/d), which brings natural gas from northwest Pennsylvania to an interconnection with the Mountain Valley Pipeline, are also scheduled to come online in 2018. The first phase of Rover Pipeline was completed in late 2017, and Phase 2 is expected to come online in mid-2018. Phase 2 includes 3.25 Bcf/d of new capacity into Midwestern markets and the Dawn hub in Ontario, Canada. NEXUS Pipeline Pi peline,, which whi ch follows f ollows a simisi milar route to Rover, will add 1.5 Bcf/d of new capacity. Natural gas from the Marcellus and Utica basins will be delivered to this pipeline by the 950 MMcf/d Appalachian Lease Project, also scheduled to come online in 2018. Separately, nuclear, coal and older oilfired power plants are rapidly being shut down and replaced by more-efficient and cleaner-burning gas-fired facilitiess. Con Edison, for example, said between 2012 and 2016, more than 5,000 large New York City buildings switched from oil to natural gas for heating. Additionally, according to RBN Energy, the Northeast Gas Association (NGA) 2017 Regional Market report showed natural gas heated homes in the Northeast grew by more than 1million since 2008. Three projects associated with the Transcontinental Gas Pipeline are intended to add more than 3 Bcf/d of capacity out of Pennsylvania and West Virginia. Virginia. P&GJ

Existing and planned natural gas pipelines in the northern United States

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Bozick

Getting into the Pig Launcher Groove

By Adam Bozick, Regional Manager, Victaulic

P

ipeline pigging is an important part of ensuring reliable pipelines and, when done as part of a larger maintenance program, can significantly significantly reduce the risk of line failure and downtime. Clearing buildup or blockages from gas hydrates, asphaltenes,, iron oxides, scale or paraffin is asphaltenes just one way in which pigging pigging helps manage line integrity. Pigging is also routinely used to identify damage from corrosion before it becomes a major issue. This process, however, can be costly and time consuming with traditional pigging equipment.

Necessity of Pigging In hydraulic fracturing operations, a site may have low elevation areas in the gathering system where liquids, chlorides, old chemicals or proppants can accumulate. Slugging from this can cause particular challenges for pigging, restricting flow in the pipeline and slowing production. To avoid these issues, operators may utilize lay flat hose, which offer advantages in trans port and storage storage volume volumess along with ease of handling. These hoses, however, can still present issues like ice and debris clogging them. Any line, traditional or lay flat, that is not pigged frequently can become a danger. To avoid unplanned downtime for costly repairs, inline inspection should be planned and performed to ensure line integrity. Routine pigging is just one part of this, but helps ensure that lines are clear and leakfree. In some projects, lines may need to be pigged frequently. In those cases, and in remote areas that are difficult to get pigging equipment to and from, installing multiple pig launchers in the system may be helpful.

When Pigs Y Traditional pig launchers for lay flat hoses in the field include a “farmer fitting” (flanged Y lateral) and various flanged valves. An 8-inch version of this system weighs somewhere in the neighborhood of 730 pounds. Go up another 2-inch for a 10-inch system, and that weight goes up to over 1,100 pounds. In the field, we know that weight (and space) equal money. Even getting this hefty equipment onsite can be a challenge; it requires additional coordi38

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nation and cooperation with on-site and off-site crews, and they must wait for the appropriate weather conditions before ship ping the equipment. The challenges don’t stop at logistical issues, either. On the operations side, we know that flanged valves can be difficult and time consuming to install. They can also make maintenance of the pig launchers more difficult, as flanged valves are more difficult to disassemble and require a special tool. Cycling these valves a few times each week also wears away at the valve seat, incurring additional maintenance costs to maintain the valves. It can be difficult, also, to source parts for pig launchers in remote locations. In a desperate attempt to get back online, operators may unknowingly source parts from a local supplier that is not CWS listed or that does not pickle and passivate their welds to prevent oxidation. This opens operators to any number of risks if the valves, fittings or pig launcher fail from not being welded to the minimum pressure code.

So, What Do We Do? By simply replacing the bulky flanged connections of the traditional pig launcher system with grooved assemblies, operators can significantly reduce the weight of their pig launcher systems. The same 8-inch system is reduced to about 350 pounds, while the 10-inch system comes in at 575 pounds. For a site that needs ten pig launchers, this means a savings of over 3,800 pounds (or 5,250 pounds for the 10-inch version). This weight reduction makes transporting the equipment easier and directly translates into fuel savings for the operator. Pig launchers with grooves instead of flanges are much easier to operate. The enormous force that is required to open a flanged valve is eliminated by the better breakaway torque of grooved valves. The built-in “snipe” (a sort of cheater bar) makes it much easier to open and close these valves. The two bolts on a grooved system are removed with a simple impact gun. When not in use, the grooved couplings can be used in other areas of the site – for example, when connecting pumps, valves and fittings to lay flat hoses during everyday operations. Of course, this simple assembly and disassembly makes pig launcher main-

tenance in grooved systems much easier as well, and reduces r educes safety concerns.

Case Study An operator in northern Alberta and British Columbia used a 10-inch, grooved pig launcher for a year. The older flanged system they had been using took two hours to install, per pig launcher launcher.. The new groo grooved ved system system took only 10 minutes. Because of the flexibility and simplicity of the system, crews were able to utilize the same components from the pig launcher for lay flat assemblies and pump bypass byp asses es when when the the launch launcher er wasn’ wasn’tt in use. use. These grooved valves could be operated with much less torque and for longer periods between betwe en mainte maintenanc nancee than the traditio traditional nal flanged valves. When routine maintenance was needed, the crews could quickly get the system back online due to how easy the grooved system was to repair in the field. The ease of operability, functionality and flexibility have led to the operator’s decision to use the grooved pig launcher assemblies at other sites.

Doing Things Differently Operators are pushing, daily, to reduce their costs in a market where oil prices can vary widely. Without compromising safety, streamlined operations are a premium, which is encouraging operators and builders to improve asset efficiencies and invest in technologies with a higher ROI than what the status quo would provide. To do things better, we we need to do things more more efficiently – and that means doing things differently. differently. For the requisite pig launching systems of many operations, this may mean utilizing grooved assemblies instead of the traditional flanged designs that, while they still get the job done, do not offer the biggest bang-for-your buck. bu ck. Des Design ign ch chan ange gess that that can can disr disrup uptt that that stastatus quo are taking root, allowing engineers to look at problems from a different point-of-view to solve challenges more efficiently. P&GJ Author: Auth or: Ada Adam m Bozick Bozick is a regional manager

with Victaulic, a manufacturer of mechanical pipe join joining ing and fir firee pr protec otection tion sys system tems, s, whe where re he works with customers in the upstream and downstream markets. He is a member of both the Construction Industry Institute and Rice’s Engine Eng ineerin ering g & Const Construc ruction tion For Forum. um.

Real-Time Views of Measurement for Performing Data Analytics By Russel Treat, CEO, EnerSys Corporati Corporation on

A

s the CEO of a software company that provides technology and tools to support pipeline operators, I hear a lot of chatter about data analytics. Everyone wants access to the latest data at their fingertips – to be more efficient, run safely, save money, and remain compliant. However, some operators are looking at the chasm between data and analytics, and are wondering how to build a bridge from data to the effective use of analytics. Real-time views create meaning and context for the data, benefiting everyone in your operation. Also, real-time views provide information about the process – or, said another way – information about the quality of the measurement. You might be saying to yourself, “I already collect data in my SCADA system, so why would I need a real-time measurement system?” The key in answering this question is in understanding who is using the data and for what purpose. While the same data is going into the SCADA system, the real value is the view for measurement. SCADA is looking at how much flow there is right now. However, measurement is looking at how good and reliable the num bers are and will they line up at the end of the day when I provide end-of-day reports? Everyone is looking at the same data, but everyone needs different information. Ideally, data is contextualized for each role in the operation such that the view into the information supports their specific decision-making. The contextualization is how I look at the information. When everyone in your operation has the data properly contextualized for their role, there is a significant impact on each person’s ability to determine what actions are required. When the data is contextualized in real-time, decisions can be made now vs. reactively making decisions after events have passed.

Solving Real Problems One of the best examples of the value of real-time data in measurement is keeping a history of real-time values such as temperature and differential pressure on an orifice meter. When you look at these values at the one-minute level – or even more frequently

– you are provided with a much different view than what an hourly average would typically provide. For example, by trending real-time temperature and differential pressure, you can see a meter freeze occur. Ultimately, a real-time view of values could be the difference between catching an issue or dealing with it after the fact. Summarized data just is not enough for stakeholders to make optimal decisions. In the example, the meter occurs and is clear in less than an hour. Typically, the measurement back office is only looking at hourly summarized data. It would be impossible to identify this meter freeze using hourly summary records as the freeze would be buried in the summary. Here’s another example: Flow computers typically accumulated and summarized measurement into hourly records that are moved back to the measurement back office. This hourly summarized data A view of rate, temperature, differential and pressure. is critical to the measuresummarized rized data? Consi Consider der meament back office function in that it allows pared to summa surement alarms tied to events in the system. for editing and reporting while retaining a Again, referring back to the meter freeze, measurement audit trail. However, it is not uncommon in some by creating an advanced algorithm using operations for the measurement data to be advanced analytics, an algorithm can be collected only once every four hours, or created that uses the complete meter condieven daily. By the time the measurement tion – temperature, differential pressure, static pressure, composition and moisture office gets that data, the back office could be a day behind in reacting to an alarm. content – to calculate when a hydrate would Polling the measurement device for real- form. This makes a meter freeze notification even more meaningful. time data consumes much less bandwidth Essentially, your operation needs to folthan the full hourly audit file and allows for low a six-step process to use data analytics early identification of problems. Where else can you find much more effectively: 1. Collect the data in your system. system. meaning and context in real-time data comwww.pgjonline.com

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2. Normalize the the data in your common structure. 3. Use real-time views to find the meaning and context of to the data. 4. Perform manual manual analytics analytics to determine use cases. 5. Implement the the algorithms to identify abnormal conditions. 6. Create a procedure to address address the abnormal conditions.

Applying Analytics

Think about the importance of communication in the field. Is it productive for a measurement technician to send an email to the measurement office with his findings on an orifice meter, wait two hours for a response and then take action? Absolutely not. That is entirely inefficient when there are other technological options to speed up the communication process. Similarly, the key signals coming back from a meter are much more meaningful if both the field and back office can look at them at the same time, discuss the trends and respond accordingly. For example, a meter freeze will display a typical pattern in its relationship between temperature and differential pressure. When both the field technician technician and the back back office can look at the same pattern, they form a common understanding and define a collaborative path forward to resolve the freeze. Specifically, you should be able to identify when the freeze began and ended. If you are summarizing the data, it becomes much more difficult to see the issue. Additionally, if you are only seeing the data from a meter freeze at the end of the month, then you must go back through the entire month to edit the data – and you missed an opportunity to react to the meter

freeze in real-time. Conversely, if you have the capability to catch the meter freeze during the month, then you can send a technician out to the meter to clear the freeze, minimizing measurement error and simplifying the end-ofmonth closing process.

Time Savings Once you develop and implement a consistent process for using real-time data, you can tap into more methods to use advanced measurement capabilities capabilities in the field. Fortunately, the latest technology available for SCADA systems makes it easier to utilize telemetry to perform real-time measurement functions. A useful example is a gas stream with multiple meters, where the chromatograph is located in such a location that it cannot be shared in the local communications. For example, at a plant site where inlet meters are remote from the meters at a process inlet, the chromatograph at the plant inlet can be polled and written to the chromatograph at the process inlet. This process eliminates the need to install additional chromatographs, delivering tremendous cost savings. Consider this scenario: � There are three gas processing trains at

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©2018 Caterpillar. All rights reserved. CAT, CATERPILLAR, BUILT BUILT FOR IT, their perspective logos, “Caterpilla r Yellow”, the “Power Edge” trade dress as well as corporate and product identity used herein, are trademarks of Caterpillar and may not be used without permission. www.pgjonline.com

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the same facility (process ( process inlets), and three different customers making deliveries to the facility (plant inlet). Each of the three plant inlets delivers to each of the three train inlets. Only the plant inlet meters have an online gas chromatograph (GC), so the plant takes a chromatographic reading at the source and communicates the data to the train inlets. Instead of purchasing 12 GCs for each of the train inlets (3-by4), the plant just needs three GCs at the points of delivery.

Real-Time Views as seen on the EnerSys POEMS IOC.

Real-time telemetry helps facilitate the plant’s ability to perform accurate measurement. Then, once the data is gathered in real-time, stakeholders in the plant can perform data analytics. A software tool can help you manage the process of obtaining realtime data, viewing the data and taking action. And, because there is so much measurement data coming into your operation, you also need a tool that can help simplify the process to provide accurate, timely data for operational decision-making. One such tool is the EnerSys IOC intelligent operator console (IOC) for measurement from my company’s POEMS software suite. This tool provides users with real-time access to data from flow computers, PLCs and gas chromatographs. Using a communication server, the appropriate measurement device is regularly polled to provide operators with real-time data. You can also create a demand poll of a specific device at any time to gather data. The software is set up to provide multiple views for each stakeholder in the operation. This allows users to perform tasks such as viewing live gas quality from all GCs and reading/writing configurations back to the GC. We understand the importance of having a central location to collect, view and store the data collected from your measurement devices. That is why our company continues to talk to operators to understand the challenges of moving to real-time data views. Remember,, if the conversation in your pipeline operation is movRemember ing toward data analytics, you need to start with how to implement a process for real-time views in metering and measurement. Taking Taking this step will set you on the right path to achieve operational operational excellence, become more efficient, operate safer, and remain compliant with the latest pipeline regulations. P&GJ 42

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CAPABILITIES GUIDE

IT ALL STARTS WITH API 1169 PIPELINE CONSTRUCTION INSPECTOR CERTIFICATION.

An energy revolution sparked by dramatic gains in crude oil and nat ural gas production in the U.S. and Western Western Canada, along with the aging of the existing pipeline network, has produced a series of major pipeline construction projects. This has led to a growing demand for skilled and knowledgeable pipeline construction inspectors. API’s Pipeline Construction Inspector Certification Program provides the oil and natural gas industry with a standardized and unbiased process for certifying qualified individuals who perform pipeline construction inspection activities. Through experience experience verification verification and testing, the certification certification process identifies competent inspectors who possess the basic credentials required to perform the duties to best industry practices and standards. With the hiring process proc ess now now simplifi simplified, ed, pipeli pipeline ne operato operators rs can feel confi confident dent that that an APIcertified inspector is capable of performing the work safely and efficiently. ARE YOU QUALIFIED TO TAKE THE API 1169 EXAM?

API 1169 Pipeline Construction Inspector Certification requirements are based on work experience acquired within the last 20 years. Education and other certifications may also be needed.

Determine which category applies to you and then provide the information that is required. • The minimum amount of experience/education needed to qualify MUST be documented on your application and will be verified after your application has been submitted. • If you are using education or certification certification to help you qualify, qualify, then official documentation (in the English language) will need to be uploaded into your application. Career advancement is spelled ICP. Whether you’re an experienced inspector or just beginning on this exciting career path, becoming an API-certified Pipeline Construction Inspector is your first step in career

advancement. Join over 4,000 certified 1169 inspectors and demonstrate you have the knowledge, skills and professionalism required to get the job done right. Sign up for the next available exam and prove your knowledge. For more information, visit www.API.org/PipelineInspector www.API.org/PipelineInspector..

Individual Certification Programs: ICP Applicants can qualify in one or more of these categories. • Pipeline Inspection Experience • General Oil & Gas Industry Inspection Experience • Non-Inspection Pipeline Experience • Non-Inspection General Oil & Gas Industry Experience • Other Heavy Industry Experience

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A FULL-SERVICE SUPPLIER DELIVERS PROJECT BENEFITS

A horizontal direction drill (HDD) crossing from a recent project that benefitted from Burns & McDonnell’s multiple service c apabilities.

When tackling the various tasks and requirements of a pipeline project, multiple services integrated within a single, efficient project team offer numerous advantages. A full-service pipeline service supplier can providee the integra provid integration tion that can help help you you realize realize the followi following ng benefit benefits: s: • • • • • •

Shorter schedules Reduced owner risk Greater cost controls A single point of responsibility Increased cooperation Enhanced design and construction construction innovation innovation

There is no question that pipeline projects are becoming more complex. Among the reasons a full-service supplier makes sense: 1. Pipeline projects are going beyond engineering and construction. Pipeline projects increasingly require efficient permitting processes and effective community relations. To help a project be successful, the project should incorporate the permitting process and community relations from the beginning. Obtaining permits is often in the project’s critical path, and early, open communication is the best way to achieve community support.

reduced, because there is no need for a design firm to provide permit material to another company. 3. Even supporting a full-service, broad experience strengthens the overall project. A supplier that has the capability to deliver multiple services understands more aspects of the overall project, even those not in its scope. These firms can add value simply because they are familiar with the scope that is being executed either by another supplier or the owner directly.

ABOUT BURNS & MCDONNELL With decades of experience serving the oil and gas industry, Burns & McDonnell is uniquely positioned to provide a full range of services, including environmental permitting, land acquisition, community relations, design, procurement and project controls. We have the capability to perform or manage a combination of those services as a single, integrated package or individually, depending on project requirements and our clients’ needs. We do offer full EPC services to provide additional flexibility to our clients and our program management experience includes small and mega-sized projects.

2. Integrated services bring efficiencies. Working with suppliers that deliver multiple services makes it easier for the owner to manage the schedule and increase cost-efficiency.

CONTACT INFORMATION: When a supplier is working on land acquisition as well as design, the coordination to obtain survey permission from just one supplier alleviates the chance of data getting lost or a task not being completed as required. The supplier can manage these crossfunctional activities of the project internally and keep the client informed. There is also a decrease in requests, and wait time is

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CAPABILITIES GUIDE

DENSO PROVIDES THE PIPELINE & TANK TANK INDUSTRY INDUSTRY WITH A VARIET VARIETY Y OF ANTI-CORR ANTI- CORROSION OSION PRODUCTS PRODUCTS

Denso North America offers a wide variety of anti-corro anti-corrosion sion and sealing products with a proven track record of solving problems in all kinds of challenging environments, above or below ground and underwater.. With manufacturing plants worldwide, Denso is recogunderwater nized as the gl obal leader in corrosion prevention. Denso’s vast line of products include Protal Liquid Coatings, petrolatum tapes, mastics, primers, bitumen & butyl tapes, hot-applied tapes, SeaShield Marine Systems and Tank Protection Systems. Protal Liquid Coatings are used for girth welds, tie-ins, cadwelds, boring applications, repairs to FBE, f ittings & fabrication, and rehabilitation of existing pipelines. Protal Liquid Coatings have become the choice of many contractors, engineers and owners in the pipeline industry i ndustry.. Denso Tape was developed over 80 years ago for the “Long Life Protection”” of buried steel pipelines against corrosion. tion

The petrolatum tape system consists of Densyl Tape, Denso Paste, Denso Profiling Mastic and various outerwraps. Denso also offers a full f ull line of SeaShield Marine Pile Protection Systems. Systems. These products include fiberglass forms, petrolatum tape/wrap systems, epoxy grouts, underwater grouts, etc. Denso has expanded to provided their t heir great tape and coating products for tank protection with the Archco line and tank base chime protection system. Denso North America’s products and systems are backed by a team of qualified professionals and offer technical support and on-site guidance. With offices throughout the USA and Canada, Denso North America is a subsidiary of Winn & Coales Interna International. tional. Winn & Coales was originally established as a business in London, England, in 1883, and the first petrolatum tape manufactured in the UK was Denso Tape, manufactured manufactured under license by Winn & Coales (Denso) Limited.

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CAPABILITIES GUIDE

ENDURO PROVIDES “EXPERIENCED BASED” SOLUTIONS FOR THE ENERGY INDUSTRY

Enduro Pipeline Services, Inc., from the beginning of this vertically integrated company company in 1988 to the present day, offers services and sales to assist our Oil and Gas Industry clients with their pipeline problems. The founders of Enduro believe in a hands-on approach to solving pipeline challenges and providing optimum solutions through the design, manufacture, and supply of cost effective pigging products. The first tool developed by Enduro was the analog Geometry Inspection Tool. This instrumented pig could detect dents, buckles, pipe wall changes, along with welds and valves. A modification was later added to the tool enabling bends to be d etected along with the geometry. In 1998, the Enduro DdL™ Integrity Survey tool was developed by Enduro and replaced the standard analog inspection tool. The DdL™ incorporates geometry inspection, bend analysis and map production into a single pass t hrough the use of digital memory. The digital storage ability also allowed the tool to be expanded into a multi-channel tool capable of logging radius point and diametrical point data, also al lowing o’clock positioning of the anomalies being recorded. This first of a kind geometry inspection tool, to ol, placed the Enduro DdL™ Integrity Survey Tool at the forefront of the industry and became the industry standard. The DdL™ computer flash memory, with advanced software, enabled a long line section to be measured with one pass, since the graph paper scale to pipe length was no longer the determining factor; line lengths of 300 miles can now be achieved. Since 1988 Enduro has been a leader in the North American geometry inspection market. In 2005 Enduro announced its Enduro DfL™ Magnetic Flux Leakage Survey tools - the latest development to become an integral part of day to day pipeline operational and maintenance maintenance activities. The Enduro DfLtm tool simultaneously collects five (5) data sets – metal loss, deformation, inertial, internal/external discrimination and residual field concurrently to greatly simplify the process of i dentifying features and anomaly types. Enduro’’s design team, with over 50 years combined experience in the Enduro development of pipeline inspection tools, regularly upgrades these state of the art tools with new i nnovative features. features. Enduro Pipeline Services, Inc. offers In-line Inspection Services comprised of ILI surveys utilizing our fleet of high resolution MFL multiple technology tools (DfLtm) currently available in pipe sizes 4-inch thru 36-inch, plus several dual diameter pipe sizes. PigProg II Presentertm provides advanced analysis software to vi su sual al iz ize, e, an anal al yze , an and d cre ate int er erac ac ti ve rep or orts ts for ea ch su surv rv ey. Our In-line Inspection services include Caliper/Geometry Surveys for ‘new construction’ pipelines, plus ‘on-stream’ Caliper Surveys. Enduro also features Weld Correlation Reporting to provide a complete Pipeline Listing Report including; Customer Weld Numbers, Customer Stationing, applicable Field Notes, plus GPS Data to produce KMZ files. We also offer Pipe Dent Strain Analysis, Analysis, Pipe Bend Strain Reporting, and Historical Data Comparisons in support of customers’ ongoing IMP efforts. Additional service s include: project project management, cleaning, AGM equipment/placement, and tracking equipment/services.

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Enduro offers the industry a full line of pipeline cleaning pigs, realizing cleaning is an essential p art of the internal integrity management of the pipeline. Enduro pipeline scraper products include - Uni-body urethane pigs (UreCasttm), metal body pigs (Advantagetm, Bi-Directional, and Profile), two and three section pig trains, dual and multiple diameter designs, plus we manufacture an intrusive pig passage indicator – Pig Poppertm. Custom design of pigs is a regular service offered by Enduro. As a manufacturer, we operate a modern polyurethane plant where we pour all urethane components using (MDI) composition polyurethane. polyurethane. The result - providing our customers a superior, longer lasting product for long and multiple pig runs. We increased the size of our facility in 2013 with new IT offices, training facilities and an expanded production area. This means improved quality control, decreased turnaround times, and a new Enduro client software training program. All Enduro Products and Services are ‘experienced based’ solutions to meet and/or exceed our customers’ business requirements. We invite your inquiries to learn details of your application.

CONTACT INFO:

P.O. Box 3489 • Tulsa, OK 74101 5002 S. 45th W. Ave. • Tulsa, OK 74107 800-752-1628 • 918-446-1934 Fax 918-446-8125 info@ enduropls.com www.enduropls.com

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REFINED PRODUCT SAMPLING USING THE PASS (PROGRAMMABLE AUTOMATIC SAMPLING SYSTEM) MAKING AUTOMATIC AUTOMATIC SAMPLING MORE EFFICIENT Inline sampling is essential for ensuring the overall quality of petroleum products and is used for monitoring crude oil, refined fuels and other process fluids. Sampling provides important insight into process variables such as water content and overall fluid quality. Sampling is often required for custody transfer applications and is also valuable to producers, producer s, refiners, refiners, and operators looking to keep keep their processes operating at optimal efficiency. Oil & Gas Process Solutions (OAG-PS) PASS Refined Product Sam pler (patent pending pending)) is built specifica specifically lly for for fast fast loop samplin sampling g of refined products. However, with minor modifications, the sampler can also be used for direct pipeline grabs for crude and LPG’s (Liquid Petroleum Gasses) at a constant pressure. OAG’s PASS is unique because it does not need a pneumatic system to operate therefore decreasing the time and labor required to maintain the pneumat pne umatic ic syst system. em. The pate patent-p nt-pend ending ing PASS runs with an elec electrica trically lly powered servo cylinder. The servo cylinder is adjustable for accurate control of variable sample grabs ranging in size from 1 to 75 ccs.

The system is designed to extract a representative sample and instal lation typically takes place in a bypass sample loop (fast loop) where there is a continuous flow of product. The valves and pumps are arranged so the fast loop flow runs through the entire system (circulation mode) until a sample grab is made, at which point, the main bypass valve is closed bypassing the fast loop and sending the sample to the pump where it is then commanded to inject the sample into the intended receiver. Once this process is complete, the system returns to circulate mode until the next sample grab is made. The explosion-proof rating of the PASS allows for flexibility in installation location. The PASS PASS can interface with a central PLC or control system, however, however, if need be a PLC controller or remote I/O modules can be provided. provided. Optional scales are available and are used to confirm the receiver chamber is present, and the correct sample sizes are being delivered. If desired, OAG can customize the PASS to include online inst rumentation such as densitomete densitometers, rs, viscometers or water detectors allowing for enhanced system performance and capability while providing continuous analytical measurement and sampling. In addition to refined Product Samplers, OAG-PS offers crude sam pling options. options.

LEARN MORE ABOUT OUR SAMPLING CAPABILITIES. www.oag-ps.com P: +1.602.368.20 +1.602.368.2010 10 E: [email protected] [email protected] om

Pictured above is a demo PASS sampling unit from the lab at OAG featuring some of the options available

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Oil and Gas Ga s Process Solutions Addresses Addresses your Sampling Issues.. Crude and Refined Sampling Systems to determine:

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We offer both turnkey and customized systems with optional features available to meet all of your sampling requirements.

Want W ant more info on our sampling solutions? www.oag-ps.com www.oag-ps.c om - [email protected] - 602-368-2010

Infrastructure Engineering & Construction Contractor

1-888-HENKELS [email protected]

www.henkels.com

H

enkels & McCoy (H&M) is an industry-leading contractor that provides infrastructure construction, design, and engineering solutions to the pipeline industry. H&M builds and maintains mainline transmission and distribution pipelines and related facilities to meet its customers’ needs for reliable services. While H&M is recognized for building major mainline pipelines, the company is also equally committed to completing maintenance, maintenance, repairs, and integrity maintenance for customers throughout North America. Maintaining a large national footprint allows H&M to mobilize quickly and efciently. From remote, rugged terrain to congested metro areas, no project is too large for the H&M pipeline team.

Pipeline and Facility Service Offerings • Pipeline Construction • Compressor/Pu Compressor/Pump/Mete mp/Metering ring Stations • Facility Modications • Shop Fabrication • Pipeline Integrity Management • Construction Management

Mainline • Integrity Management Oil & Gas Facilitiesment

CAPABILITIES GUIDE

WHEN FAILURE IS NOT AN OPTION WE HAVE THE DIRECT PIPE® SOLUTION The Direct Pipe® Method combines the advantages of microtunnelling and and HDD technology creating a single pass process that uses a steerable tunnel boring machine-cutting head. The technology tunnels and pushes the pipe into place at the same time, filling the void as it progresses. Overall, the process greatly lowers annular pressure acting on the surrounding subsurface formation and greatly reduces the risk of inadvertent returns. This makes the method ideal for crossing under levees and environmentally sensitive areas where failure is not an option. With the Direct Pipe® method, the entire jobsite infrastructure, including the prefabricated pipeline, is located on one side of the crossing. This set-up results in using less labor and equipment, causes less disruption to the environment, and can be implemented even in densely populated residential areas. This also makes it ideal for constructing landfalls installations where the pipeline is installed directly from the mainland out towards the open water. These benefits have led to a number number of upcoming Direct Pipe® projects projec ts due to the high and continu continuously ously growin growing g worldwide worldwide deman demand d for trenchless pipeline installations for the oil and gas industry, for freshwater and sewage transportation as well as for supply and communication lines. AUTHOR: MAUREEN CARLIN, PHD, STRATEGIC MARKETING MANAGER

Laney Directional Drilling (Laney) is the only North American trenchless company providing integrated Engineering, Procurement and Construction (EPC) trenchless services for Horizontal Directional Drilling (HDD) and the Direct Pipe® Method (Direct Pipe®). To date, Laney has executed nearly 2,800 successful crossings in 29 years of business and has completed some of the longest and most challenging HDD crossings across the globe. In recent years, Laney has expanded their portfolio and has become the North American leader in the Direct Pipe®. Of the nearly 100 Direct Pipe® crossings completed to date, Laney has completed 11 and has installed more than 23,000 feet of pipeline. This is more footage than any other contractor in North America. In November 2017, Laney set a new world-record in length for the Direct Pipe®, which included a shore approach execution into the Gulf of Mexico located in Cameron County, Texas. The total length of the 42-inch diameter installation was nearly 5,000 feet and an additional 1,350 feet of pipe pushed out to the offshore contractor. Laney utilized a Herrenknecht HK750PT thruster and clamp with a Herrenknecht AVN 1000 TBM. In addition, Laney utilized a one-of-a-kind Derrick Direct Pipe Cleaning System Set-up with 300-bbl Mixing Tank and Mammoth Centrifuge. These systems were ideal for the execution offering full f luids circulation and low pressure for minimal environmental risk. The project was completed safely, on schedule and within budget marketing the 11th successful installation in a row for Laney. Numerou Num erouss factor factorss have have led to this this suc success cessful ful reco record. rd. Prima Primarily rily,, Laney Laney is pushing pus hing ind industr ustry y safety safety stan standard dardss by util utilizin izing g advanc advanced ed techn technolo ology gy aroun around d communication and atmospheric monitoring during confined entry operations. Brian Carpenter, Corporate Director, Director, HS&E notes that, “we are improving policy around, when entries are made, why entries are needed, number of

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personnel person nel and dur durati ation on of ent entrie ries. s. Als Also, o, we hav havee ini initia tiated ted a for formal malize ized d les lesson sonss learned review process which is conducted on each project to ensure continuous improvement of all safety procedures.” These initiatives have resulted in zero lost time due to injury on all Direct Pipe® Projects. Laney is the only company with the in-house expertise to both design and construct a Direct Pipe® installation. “The process starts with our team of geotechnical experts evaluating a potential installation site for both geometri geometricc and geologic feasibi feasibility. lity. The team selects subsurf subsurface ace exploration locations based on geology, geometry, and site conditions to evaluate the potential profile,” describes Andrew Sparks P.E., P.E., Principal Geotechnical Engineer. Using the subsurface information, the engineering team designs the most appropriate Direct Pipe® profile and calculates the estimated thrust forces, installation and operating stresses, and hydraulic fracture risk. At all stages of the Direct Pipe® engineering design process, the construction team works with the engineering team to develop the design with the highest likelihood of success to execute the construction effectively, efficiently and safely. Regarding construction, Drilling Fluids F luids Engineer/Coordinator Tommy LeBlanc Sr., considers, “what differentiates Laney’s Laney’s Direct Pipe operational successes is a highly skilled and experienced construction team consisting of a strong superintendent and his core crew that have a profound understanding of the overall process. From the engineering aspect to the actual field installation and rig-up of the thruster anchoring system is probably the biggest difference maker. Once that’s well established and the excavation and tunneling operations begin the crews monitor and maintain good drilling practices which have proven to be very successful to date.” Overall, Laney’s Direct Pipe® success “in large part to our EPC capabilities which, to date, has resulted in a 100% success rate having as all of our Direct Pipe® projects have been completed safely, on schedule and within budget. Laney is constantly on the forefront of the industry by learning about about new and improved improved equipment, installation installation techniques and all around operating efficiencies. In addition, we are improving our maintenance program, upgrading our umbilical components, upgrading our communications system and staying on top of leading edge of tunneling equipment,” commented Project Manager Nick Michels. Since 1989, Laney Directional Drilling has pushed the limits of trenchless equipment and construction execution, which has resulted in numerous project records. These records are the byproduct of our commitment of excellence to our clients, to ourselves and to the overall promotion of t he trenchless industry. As Laney moves into the next generation of trenchless innovation, we will continue to drive industry standards and to provide our clients with safer, more effective and more responsible solutions to the most complex and challenging pipeline installations.

CONTACT INFORMATION 831 Crossbridge DR, Spring, TX 77373 (281) 540-6615 [email protected] www.laneydrilling.com SPONSORED CONTENT

# 1 i n D i r e c t P i p e ® i n N o r t h A m e r i c a

NEW WORLD RECORD T H E D I R E C T P I P E M E T H O D ®

ENGINEERING|HDD|DIRECT PIPE ®

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5,000’ of 42” Pipe

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Brownsville, Texas, Texas, USA

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Gulf of Mexico Shore Approach

2 0 1 7 To To p 5 0 T r e n c h l e s s E n g i n e e r i n g F i r m


ADVANCED PIPELINE CLEANING SERVICES ADVANCED ADV ANCED PIPELINE CLEANING CL EANING SERVICES N-SPEC ® Pipeline Pip eline Services (dba of Coastal Chemical Co., LLC/ Brenntag NA) is the industry standard in pipeline cleaning services since 1995. N-SPEC® is the first of the pipeline services companies to do online cleaning using its own application specific equipment, chemicals and personnel.

ADVANCED ADV ANCED PIPELINE CLEANING CL EANING The accumulation of deposits in all types of pipelines causes significant declines in operating efficiencies and throughput. The N-SPEC® Team specializes in removing wax and asphaltenes scales, black powder, iron sulfide and many other solids that can cause flow restrictions and corrosion failures in pipelines.

OFFLINE SERVICES N-SPEC® offline ser vices are performed on newly commis sioned pipelines as well as pipelines previ ously operati ng. N-SPE C® technicians are highly trained and experienced in all aspects of offline services including pipeline blow-downs, line pre-cleaning, pigging, hydro-testing, drying and commissioning pipelines. N-SPEC® Typical Separation Equipment Setup at Customer’s Re-

ELIMINATE ELIMINA TE PIPELINE DEBRIS For a myriad of applications N-SPEC® offers a complete line of pipelinee specific pipelin specific cleaner cleaners, s, specialty specialty solvent solventss and anti-fo anti-foulants. ulants. N-SPEC® cleaning chemicals will penetrate, lift and disperse solids deposits into the liquid phase to allow easy removal. These cleaners are designed to clean down to the pipe wall to cost effectively eliminate pipeline debris.

LEADING WITH WI TH TECHNOLOGY N-SPEC® offers offers the patented FloClean™ product line for dissolving elemental sulfur deposits and the patented PowderSolv™ product line for dissolving Iron Sulfide in Black Powder. The FloClean™ products will effectively dissolve sulfur deposits in a pipeline at ambient temperatures. The PowderSolv™ products are neutral pH Iron Sulfide dissolvers that do not create H2S outgassing.

ceiver Site for Cleaning Natural Natural Gas Pipeline Online

a broad range of technical services, including pipeline cleaning program designs, solids monitoring during line cleaning, and laboratory services. N-SPEC® can also provide provide customers customers with all the equipment needed for any job, including our proprietary pipeline-cleaning separators and other separation equipment. With our pipeline-cleaning separator, pipeline operators can clean pipelines online or perform system improvements without ever shutting down operations.

RENTAL EQUIPMENT Added to our fleet of equipment are ANSI 600 and 900 rated separation equipment including filter-separators, coalescer units, knockout vessels, portable flares, pig launchers and receivers along with other various associated accessories.

FLARE SERVICES N-SPEC® flares are designed for quick set-up to get your project up and running fast. Our 2-inch flare units are completely self-contained and can handle both liquid products and gas. Both the 6 and 12-inch flare units are designed to handle natural gas only. Combined with experienced on-site flare supervisors and the N-SPEC® fleet of low and high-pressure separation equipment, equipment, we can safely and reliably provide a 98% destruction rate during pipeline, plant cleaning and maintenance operations.

CONTACT INFORMATION

EXPERT SERVICES Backing up the N-SPEC® product line is a team of highly trained specialists experienced in all aspects of pipeline cleaning and pigging. With the aid of our sophisticated computer software products and inhouse analytical capabilities these specialists can provide customers with

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6127 Hwy 90 East Broussard, LA 70518 800.535.6182 [email protected] coastalchem.com SPONSORED CONTENT

EFFECTIVELY EFFECTIVEL Y TREATS IRON SULFIDE IN IN

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What is ™ PowderSolv ? PowderSolv™ is an innovative line of patent protected water based iron sulfide dissolvers. These unique products have a neutral pH that will chelate iron compounds. The reactions of PowderSolv with iron sulfide will not create toxic hydrogen sulfide gas. The by-products of these reactions remain in the water phase and are easily disposed of in a waste water system. N-SPEC’s PowderSolv will safely and effectively treat iron sulfide by batching or continuous injection in natural gas and liquid applications.

Increase in reaction efficiency *

Increase in reaction rate * * WHEN COMPARED TO THE INDUSTRY STANDARD PRODUCTS.

*IN TRADITIONAL APPLICATIONS

Remediating Black Powder Oil and Gas operators around the world cope with a wide range of system fouling solids that can lead to production loss, system plugging and corrosion failures. One of the most common system fouling solids is Iron Sulfide (FeS) also known as Black B lack Powder. Powder. Black Powder has been detected from Oil and Gas producing wells all the way to refineries. N-SPEC Pipeline Services’ patented N-SPEC ® POWDERSOLV™ is an innovative solution for the remediation of iron based Black Powder deposits in Oil & Gas systems.

coastalchem.com 800.535.6182


LET US HELP YOU PROTECT WHAT YOU BUILD WITH PIPESAK FILLING SERVICES SAVE TIME. PipeSak offers professional filling services to meet any construction schedule. With experienced crews we can provide filled geotextile pipe lin linee wei weights ghts for any numb number er of spre ads, in mult ipl e l ocat ions , 24/7. PipeSak professional crews can can often fill twice the number number of weights using the same equipment and labour as inexperienced crews or third-party contractors, contractors, saving you time. We also also provide a ROW representative to inspect and train your stringing crew on proper handling and installation procedures, making sure every weight i s installed quickly and easily. SAVE MONEY MONE Y. Cost savings are important to our customers, and important to us. PipeSak has warehouses across North America, strong relationships with our aggregate, equipment and freight providers, and experienced filling crews that help us offer our customers the most competitive filling rates - through out North America. Ta Take ke the financial risk out of your projects and let PipeSak provide you with a finished filled geotextile pipeline weight, ready for installation. GUARANTEED QUALITY QUALIT Y. When you choose PipeSak to provide your filling services you get guaranteed quality quality and service. PipeSak carefully selects the appropriappropriate aggregate to suit your climate and buoyancy design requirements. We adhere to strict quality assurance guidelines to ensure all of our filled pipeline weights meet your project specifications. We weigh each and every bag and provide our customers with daily filling reports to keep you up to date on our progress. We stand behind our products and will do whatever it takes to keep our customers customers satisfied. Our crews are ISN registered and in full compliance. Take the risk out of filling your weights and let PipeSak take care of it. PIPESAK FILLING PARTNERS – ANYWHERE, ANY QUANTITY Sometimes you only need a few weights. Sometimes you need them yesterday. PipeSak has partnered with local filling companies to sup ply our customers with competitively priced, filled geotextile pipeline weights, often next day. day. PipeSak filling partners stock filled weights and can offer trucking direct to your project. They can also deploy filling crews to fill, either in your yard or close to the ROW. INDIGENOUS PEOPLES INVOLVEMENT INVOLVEMENT PipeSak Filling Services has partnered with Native American tribes in the US and First Nation and Metis bands in Canada to provide our customers with the option to include aboriginal content in their pipeline weighting. From sourcing aggregate, aggregate, to trucking, to labour labour and equipment, PipeSak has successfully supplied large pipeline projects with our aboriginal partners for over 20 years.

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CONTACT INFORMATION: 2800 Post Oak Blvd., Houston, TX 77056 Tel: 1-866-PIPESAK Email: [email protected] Website: www. pipesak.co pipesak.com m

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PROFESSIONAL FILLING SERVICES PipeSak® deploys multiple crews to fill and stockpile any quantity of weights required to meet your construction construction schedule. Strict quality control ensures a properly filled, accurately accurately weighed PipeSak® using our specially designed Quick-Fill and release system. GUARANTEED!

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HARPSTER-TO-LIMA PIPELINE PROJECT ACHIEVES ALL MAJOR OBJECTIVES Energy Services South (ESS), a PLH Group Company, played a significant role in constructing Marathon Petroleum Corporation’ Corporation’ss new 49-mile condensate condensate pipeline in the Utica Shale region of Ohio. The com plex project was a marked success in terms terms of of safety safety,, on-time on-time completi completion, on, and quality of construction. The Harpster-to-Lima pipeline was sought for efficient and safe deli very of liquid condensate to refineries for processing into gasoline and diesel fuels.

Additionally, a “smart” caliper tool was run through the completed line to detect pipe damage. No problems were encountered, therefore zero anomaly digs were required following the caliper tool run. “Everything tested really well,” said Ryan Schroeder, business development representative for Marathon Pipe Line. “W “We’re e’re very happy with the quality that we got.” ESS President Paul Sparkman commented: “The Harpster-to-Lima pipeline attests to the hard work work of our employees and and our commitment to continually exceed our client’s expectations.”

IMMEDIATE AND LASTING IMMEDIATE L ASTING BENEFITS Pipeline connectivity of refineries offers reliability, efficiency, economic, and safety advantages. One example beneficiary of the new Harpster-to-Lima pipeline is Husky Lima Refinery Refinery.. Jason Stechschulte, a commercial development manager for Marathon Pipe Line, said that trucks can only move about 190 barrels at a time, and it would take anywhere from three to four hours for the products to get to Lima. With the new pipeline, 190 barrels can be moved in about five minutes.

CHALLENGING REQUIREMENTS The project involved installing 49 miles of 12-inch steel pipeline from the village of Harpster to the city of Lima. ESS also installed seven block valve sites and three facility tie-ins, as well well as more than 60 miles of agricultural drain tile to ensure that the soil moisture for crops on the right of way was comparable to the pre-construction state. Southeast Directional Drilling, another PLH Group Company Company,, com pleted fifteen horizontal directional directional drillings (HDD) spanning a total of 18,110 feet, passing under I-75 and other obstacles. Engineered to support a maximum capacity of 50,000 barrels of condensate per day, the pipeline will easily accommodate Marathon Pipe Line’s projected daily shipping rate of approximately 25,000 to 37,000 barrels. SAFE, ON TIME, ON BUDGET, AND HIGH QUALITY Mainline construction began in January 2018 and the pipeline was fully operational within six months – slightly ahead of Marathon’s target completion date and also slightly under budget. The Utica build-out project cons umed an estimated one million milli on working hours from more than 450 contractors, and over 350 of them were ESS resources. Notably, there were zero recordable injuries throughout the duration of project. More than 5,300 welds were applied with a high degree of quality. To To optimize weld safety and performance, each connected section of the pipeline was X-rayed, and then the full pipeline was tested with water at a pressure much higher than normal operating conditions. The project’s low 0.71% weld repair rate is evidence of the construction team’s high-quality workmanship.

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WHY ENERGY SERVICES SOUTH? Marathon Pipe Line is committed to earning the trust of the communities in which it operates, and the company chooses its service partners accordingly.. ESS is proud to have served as Marathon’s pipeline construcaccordingly tion partner on t he Harpster-to-Lima project. ESS places the utmost value on employee health and safety, and expects complete dedication to the elimination of unsafe practices and conditions. It has extensive nationwide expertise in pipeline construction, station and facility construction, and Department of Transportationrelated services, as well as strong relationships with regulators. Count on ESS and PLH Group’s other trusted entities for com prehen pre hensiv sivee exp expert ert ise in pip pipeli eli ne con constr str uct uction ion,, dir ect ection ion al dri lli ng, and energy and other services. Call us now at 214-272-0500 or visit www.plhgroupinc.com. MARATHON PROJECT PROJECT HIGHLIGHTS: HIGHLIGHTS : 350+ ESS resources 49 miles of 12’’ steel installed 15 HDDs completed 7 block valve sites and 3 facility tie-ins installed 60+ miles of agricultural drain tile installed 0.71% weld repair rate for 5,300 welds 6 months to mechanically compete mainline construction 0 anomaly digs post-caliper tool run 0 recordable injuries throughout the project duration

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CAPABILITIES GUIDE

Reliability in Flow Control for Critical Applications RELIABLE OPERA OPERATION TION WHEN IT MATTERS Rotork products provide assured reliability for critical applications. Whether used 24/7 or once a year, Rotork products will operate reliably and efficiently when called upon. CUSTOMER FOCUSED IT’S ALL ABOUT YOU

MULTI-NATIONAL LOCAL PRESENCE WITH AFTER SALES SUPPORT

At Rotork, we focus on solving customer challenges and thrive on developing new and better solutions. This focus runs from the initial inquiry through to long-term, after-sales support.

We’re a global company with an emphasis on local support. Rotork has a vast network of strategically located automation centers, manufacturing manufacturin g sites, and sales and service offices to provide fast deliveries and an unrivaled customer experience.

QUALITY DRIVEN TECHNICAL INNOVATOR Rotork product design is the result of the application knowledge accumulated in 60 years of experience. That knowledge knowledge,, coupled with our long-standing commitment to research and development , ensures cutting-edge products.

CREDIBILITY AND HERE TO STAY Rotork has been a recognized market leader for 60 years. Our customers have long relied upon us for innovative solutions to safely manage flow. You can depend upon us to be there when needed.

LOW COST OF OWNERSHIP

RESPONSIBILITY IN ALL ASPECTS

Long-term reliability prolongs service life thereby reducing the overall cost of ownership. Rotork products outlast our competitors’ solutions and provide greater efficiency to process and plant.

We believe that being a responsible business leads to being a great business and are committed to embedding this principle into every aspect of our operations. We are environmentally, ethically, and socially responsible.

MULTI-PRODUCT MULTI-INDUSTRY Rotork products and services are utilized in oil and gas, water and wastewater, power, marine, mining, food and beverage, pharmaceutical, pharmaceu tical, and chemical industries around the world to improve efficiency, assure safety, and protect the environment.

www.rotork.com

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Others sell PARTS.

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CAPABILITIES GUIDE

NEW PRODUCTS FROM CDI CDI, the world’s preeminent leader in pipeline pig detection, recording, and locating technology, has been designing and manufacturing products for use on land, offshore platforms, and subsea environments for 35 years. Known for their durability, reliability, and ease of use, CDI equipment is in use on every continent. Three years ago, their popular TRAXALL 720 and 770 hand-held receivers were released. They not only track, locate, and pinpoint pigs and MFL inline inspection tools, but have built-in GPS and Bluetooth. They can even be operated remotely from the comfort of a pickup cab, and fitted with a satellite radio to send passage notifications to a cell phone. Now, three new models have been added to the TRAXALL lineup: The TRAXALL 500, 501, and 620. Simpler, lighter, and less expensive, these new models offer an alternativ alternativee to those not needing the featurerich complexity of their “big brother” TRAXALL 720/770. The TRAXALL 620 can monitor up to three transmitter frequencies. Signal strength of each transmitter is intuitively indicated on its own horizontal row of scrolling LEDs, while a single knob adjusts the reception sensitivity of each frequency. (For operators deploying traditional 22 Hz transmitters, the 500/501 models are an ideal alternative.) Eight sensitivity settings settings are neatly divided and labeled with their recommended use: PINPOINTING (low sensitivity), WALKING (medium sensitivity), and STATIONARY (high sensitivity).

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This intuitive user interface means that the TRAXALL 500/501/620 receiver requires very little training and support, lowering the total cost of system ownership. If you have had any experience at all tracking with a CDI system (or one of our competitor’s systems) you have nothing more to learn. It’s that easy. The only other controls are LED brightness and audio mute buttons, and, of course, an ON/OFF switch. That’ss it! That’ it ! CDI handles all phases of their product line–from concept to design, prototyping, and manufacturing–at their Broken Arrow location. Everything is created on-site; electronic and mechanical devices, software, and even firmware programming. Their Broken Arrow headquarters is augmented by a network of distributors on every continent. Today, CDI products are in continual use above and below ground worldwide–in nearly every country from Argentina to Z ambia. Their Broken Arrow headquarters is augmented by a branch office in Houston, Texas as well as distributors on every continent. CDI is an ISO 9001:2008 certified company and a member of the Pigging Products and Services Association. For more information about CDI’s products, visit their website at www.pigging.com or email [email protected]. CDI is an ISO 9001:2008 certified company and a member of the Pigging Products and Services Association. �

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YOUR SOURCE SO URCE FOR INDUST INDUSTRY RY-RECOMMENDED ELECTROFUSION WIPES For nearly 50 years, FG Clean Wipes has been manufacturing specialized wipes for critical environments and processes. Our Pipe Prep Wipes are the industry’s preferred and recommended product. Pre-saturated with 96% Isopropyl alcohol, these lint-free wipes are perfect for consistent, effective and safe electro-fusion and buttfusion welds. Super high alcohol content ensures the joint is completely clean and dry within seconds for enhanced weld integrity. Be safer and more eco-friendly, use these wipes instead of bulk jugs of alcohol or other cleaning agents. Housed in compact foil packets or canisters, 96% alcohol cuts through grime and dries in an instant while lint free fabric lifts away debris and resists abrasion. Improve your pipe fusion and performance with a product made in USA. FG Clean Wipes can help you cut prep time while improving the quality of your work. Visit us at FGCleanWipes.com/electrofusion today for free samples or for more information.

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HEADLINE, APROXIMATELY 70 CHARACTERS Built With COMTEL® Technology (2 LINES)

BECAUSE BECAUSE TRACKING TRACKING YOUR PIG MANUALLY CAN BE A CHALLENGE.

lautecu sanihilicae nulpa se et il id quid utaeptios evelitio verum voloreroviti comnis dolorum liquam, ut aut ut quodici enimos cum que nate molende rfereste natem sit vel eum voluptat eum faceria volest liscipicta vendebis vendeb is repudae repudae volest, utati utatiis is non non rem eserumq eserumque ue dolut dolut aut volorae cum et as sequasitio s equasitiorr maximus et fuga. Ab ilis mil modio occ umet ulpa doluptat. Agnit que dolorem nonsed quid enis et eatection resciet quam, velis im excea cus mil imus, ommoluptae ommoluptae doloresed ulpa quisquia pe veliquis inulluptur, inulluptu r, occulpa vendae sequi id ute sim qui od et ullesti oreicturit ut et deliti dignam, unti nusda que alistio et ut voluptatati idemolu ptistibeat eture in resserum qui nobitibus expero est, sed ut et, int officiet quibuscid elessequost, cusandaepero quis ea dolut disquia sperum aut as am nonsequia abore volorita cus magnatquatin essunt, culpa volupta verferovidel et alitae dolore velicient, nime nulparit latatur sequi blaccum eni dolo este volupta spidunt spidunt estibus. as sus qui alignateni renitis di ant. Hitam hil ide di occabo. Faccus corero ese mintion sendem veles molorata sapicimi, ipsa poreiur? Ur aut exceaquatur? Ulpa pratem et, odici nonessunt volorunt ipsapero exceribus eos etus sinture ea consequ atiurecabo. Et restian iHitam hil ide di occabo. Faccus as sus qui alignateni renitis di ant. Hitam hil ide di occabo. Faccus

PHOTO OR GRAPHIC

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HEADLINE, APROXIMATELY 70 CHARACTERS (2 LINES) lautecu sanihilicae nulpa se et il id quid utaeptios evelitio verum voloreroviti comnis dolorum liquam, ut aut ut quodici enimos cum que nate molende rfereste natem sit vel eum voluptat eum faceria volest liscipicta vendebis vendeb is repudae repudae volest, utati utatiis is non non rem eserumq eserumque ue dolut dolut aut volorae cum et as sequasitio s equasitiorr maximus et fuga. Ab ilis mil modio occ umet ulpa doluptat. Agnit que dolorem nonsed quid enis et eatection resciet quam, velis im excea cus mil imus, ommoluptae ommoluptae doloresed ulpa quisquia pe veliquis inulluptur, inulluptu r, occulpa vendae sequi id ute sim qui od et ullesti oreicturit ut et deliti dignam, unti nusda que alistio et ut voluptatati idemolu ptistibeat eture in resserum qui nobitibus expero est, sed ut et, int officiet quibuscid elessequost, cusandaepero quis ea dolut disquia sperum aut as am nonsequia abore volorita cus magnatquatin essunt, culpa volupta verferovidel et alitae dolore velicient, nime nulparit latatur sequi blaccum eni dolo este volupta spidunt spidunt estibus. as sus qui alignateni renitis di ant. Hitam hil ide di occabo. Faccus corero ese mintion sendem veles molorata sapicimi, ipsa poreiur? Ur aut exceaquatur? Ulpa pratem et, odici nonessunt volorunt ipsapero exceribus eos etus sinture ea consequ atiurecabo. Et restian iHitam hil ide di occabo. Faccus as sus qui alignateni renitis di ant. Hitam hil ide di occabo. Faccus

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Two line caption Giatus quunt omnis re, ommoditet lab inihicae. Ximus, et quas debis CONTACT INFORMATION Address Phone Fax Email Website

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Midwestern’s M220C and M170C sideboom attachmen attachments, ts, designed specifically for John Deere’s 1050K PL platforms, are at the head of the class. Midwestern has been designing, manufacturing, and installing sideboom attachments on John Deere Construction Equipment for over 50 years. The M220 C and M170C attachments are our latest additions. These fully integrated integrated sidebooms sidebooms deliver deliver unsurpassed visibility visibility,, operating ease, and a low low profile design that provides balanced weight weight distribution for optimum lifting. The two sidebooms offer maximum stability, low ground ground pressure, and lift capacities of 220,000 lb and 170,000 lb. HIGHLIGHTS • Maximum operator visibility • Multi-functional joystick controller • High capacity capacity pipelayer pipelayer winch package package SAFETY • Oval-track platform for maximum stability • Electronic boom stop switch • Emergency free fall function • Load Indicator System Midwestern is the industry leader in sideboom attachments, accept no imitations. M220C on JD1050K PL220

sidebooms.com

As the premier portable two-in-one Hydrostatic Testing Units in the pipeline industry, Midwestern’s HTU-350/500 automatically fill and test pipelines in one step. These units offer the fastest fill rate based on horsepower input with automatic switchover for filling pipe, pushing pigs and pressure testing. That’s how Midwestern stands up to the pressure.

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CAPABILITIES GUIDE

CAPABILITIES GUIDE

HEADLINE, APROXIMATELY 70 CHARACTERS (2 WHAT LINES) DOES IT MEAN TO BE BEST-IN-CLASS? lautecu nulpa se opportunities et il id quid You wantsanihilicae the best educational utaeptios verum voloreroviti comnis to give youevelitio the greatest chance at succeeding in dolorum ut aut ut quodici enimos cum life and inliquam, your career. NACE wants those same things for you. Our

que nate molende rfereste natem sit vel eum commitment to make you best-in-class means voluptat eum have faceria volest lisc ipicta vendebis liscipicta we ourselves to be best-in-class. But how repudae utatiisand nonraise rem the eserumque does onevolest, push itself standarddolut in a marketplace where we’re already ranked well

SUPPORTIVE COMMUNITY Being NACE certied makes me: responsible and loyal to my work; highly condent during my job-related communications and discussions with others; and unique from ordinary engineers. After completing NACE certication, I really felt a big dierence between 1 my past and present position. ⁄ 2-PAGE DISPLAY AD NACE is itself a complete platform where you can approach everything: worldwide job opportunities, access to standards, regular industry updates, and much more. – Manish Saini, NACE Cathodic Protection Technician (CP2) Certifed,

Cathodic Protection Engineer at Sanmarg Projects (P) Ltd. Saharanpur,, India Saharanpur

NACE Career Development, your experts in corrosion certication

Developed by Industry, Globally Reco Recognized. gnized.

nace.org/career-development

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Pipeline & Gas Journal SPONSORED CONTENT

• •

July 2018

aut volorae cum et as sequasitior et above the competition? At NACE, maximus we compete fuga. Abno ilisone milbut modio occ umet ulpa doluptat. against ourselves. Agnit que students doloremcomplete nonsed quid enis et educaeatecWhen their NACE tion velis im excea cthat us mil tion, resciet they’vequam, studied coursework hasimus, been ommoluptae doloresed ulpa quisquia pe veliquis through an exhaustive process. NACE courses are inulluptur, inulluptu r, occulpa s equi by sequi id ute sim and qui maintained, overseenvendae and reviewed the best od et experienced ullesti oreicturit ut et deliti dignam,inunti most corrosion professionals the nusda que alistio et utcomprised voluptatatiofidemolu industry. industry . Committees, industryptistleadibeat eture in resserum quithat nobitibus expero ers, work year-round to ensure courses are kept est, sed ut and et, int officiet quibuscid elessequost, up-to-date challenging. Their collective recogcusandaepero quis disquia sperum aut nition as the best in ea thedolut industry means they hold as am nonsequia volorita cuswork, magnatthemselves to highabore standards in their and quatin essunt, culpathe volupta verferovidel et alithey truly care about next generation continuing tae velicient, nimeindustry nulparit latatur sequi anddolore improving upon their advancements. blaccum eni dolo estepassion voluptaand spidun spidunt t estibus. Because of their commitment, as sus NACE andqui and its alignateni committee comm itteessrenitis do not notdi beant. believ lieveeHitam in cutcuthil di occabo. corero ese mintion tingide corners, takingFaccus shortcuts or cheapening the sendem molorata prempor material veles and course itself.sapicimi, Instead, ipsa NACE and its poreiur? aut exceaquatur? Ulpa pratem et, instructorsUr position students for success by providodici adiore nonessunt quia volorunt ing comprehensive training that does notipsapero exclude exceribus etus ea consequ atiurematerial to eos make thesinture course easier or faster. cabo. Etlike restiansequ atiurecabo. Et restia as sus Just our committee members, our instrucqui renitis di ant. Hitam hil ideare di torsalignateni are industry experts themselves who occabo. Faccusvclignat ide di occabo. Faccus personally perso nally – not not solely hil financially financi ally – invested invested in as qui alignaten hil ide diand occabo. Faccus as thesus organization and industry, who genuinely sus qui alignateni i eni renitis diendure ant. Hitam hil want to teach. NACE instructors a lengthy, ide di occabo. Faccus as sus qui alignateni hil ide stringent process to become an instructor. di occabo. Faccus as members sus qui ali and instructors’ Our committee dedication of time and resources to providing you with a quality education is an extension of NACE culture itself. NACE maintains an ISO 9001 certification, meaning we follow best practices in design and development of our courses. Our coursePHOTO design methodology isn’t just tried OR GRAPHIC and true for NACE,file ourtypes instructors and students. Acceptable include PSD We adhere tofiles quality management systems or TIFF (flattened, CMYK, 300 that only the elite organizations worldwide have dpimost at actual size) or vector-based achieved and put into practice. EPS files. When looking for training, you’ll be approached by many companies that compare themselves to NACE. How do you identify an elite organization? Our course development and content will always be original. Our instructors Two line caption will always build on our comprehensive course Occulparum inus, illesed exceperuptur sunt content by incorporating their industry expertise. CONTACT INFORMATION Our students will finish their NACE coursework withAddress a strong, thorough understanding and be prepared prepar ed for for the the next next step step in their caree careers. rs. Phone To be best in class, it means learning from a Fax best-in-c bestin-class lass prog program. ram. It mean meanss there there can be only Email oneWebsite choice for corrosion training: NACE.

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CAPABILITIES GUIDE

INTRODUCING OPTIMAINIM: INTEGRITY MANAGEMENT FROM WELL TO BURNER TIP For more than 25 years, Opvantek has bee n di diggi ggi ng dee p to get re real al,, mea nin gfu l information from every imaginable source of data. We deliver software solutions that make best use of your data, with proven results, and dedicated customer service. Our highly configurable, best-in-class solutions help to reduce risk, minimize your operating expenses, and improve public safety. Opvantek is proud to announce the next generation of Integrity Management software: Optimain IM .

Do you know what lies below the surface?

Optimain IM is a web-based software platform built upon the proven capabilities of the Optimain product family. The data you need to make well-informed integrity management decisions flows from many different sources with varying quality and reliability. Based on nearly 30 years of industry experience, Optimain IM automatically gathers the data, filters out the noise, enriches it via intelligent assumptions, and delivers a mathematically-sound, defensible evaluation of risk across your system. Forge a more positive relationship with your regulatory agencies by instilling confidence in your approach to risk mitigation. Use risk to justify and optimize the use of available resources - from capital investments to operating expenses to people and time. See the risk in your system at any level – from city block to service territory. Display risk directly on your GIS maps and use built-in analysis tools to visualize and summarize risk by threat categ category ory,, asset asset type, or any any other avail-

Your data has plenty to show you. OptimainIM tells you where to focus. Combine all the knowledge you have about your system and the threats it faces to produce a single, consistent, mathematically sound risk evaluation.

able dimension. Optimain IM offers a single, consistent risk

Integrity Management and Pipeline Safety

model for DIMP, TIMP, and pipeline safety management. Deploy it in the cloud or on prem ise ise,, wit h a n arc archit hitect ecture ure tha thatt scal es to meet the needs of any size utility.

Evaluate risk for individual assets across every threat category Prioritize risk mitigation actions Reduce operating expenses while mitigating risks Support pipeline safety management programs Demonstrate continuous improvement

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| 75

CAPABILITIES GUIDE

PIPE SPRING LLC LLC PROVIDES PROVIDES PIPELINE INTEGRITY INTEGRIT Y ENHANCEMENT PRODUCTS Pipe Spring LLC is a company “founded because integrity matters.” The company specializes in pipeline integrity enhancement products prod ucts incl udin g t hose that stru ctur all ally y r einf orce stee l pipe pipelin lines. es. After two years of development, we are proud to announce commercial deliveries will commence on July 1, 2018. Our staff has over 40 years of experience in the pipeline integrity and welding business and has been on the front lines of integrity issues for several decades. You You can trust Pipe Spring LLC to deliver products that protect your assets, your people, the public, and the environment. Pipe Spring LLC uses isotropic steel laminated sleeves and state of the art adhesive to repair metal loss defects, augment long seams, upgrade class locations, and other applications as appropriate. The reliable engineering data and analysis regulators require has been conducted and documented by the industry’s leading PhD level thought leader. For documentation requests please email [email protected]. Pipe Spring LLC’s patent pending technology out performs tradi tional steel sleeves and composite repair products. Operator Qualification (OQ) training is available for Pipe Spring

Integrity Subject Matter Experts, trainers, and installers. Pipe Spring LLC: � Expanded Capabilities � Enhanced Integrity � People You You Can Trust Trust

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Metal Loss Defects Long Seam Augmentation Class Location Changes Pressure Uprating Operational Changes Featuring Isotropic Steel Laminated Sleeves

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SPONSORED CONTENT

High-accuracy data without missing a beat.

Pipetel works here. Get the data you need, even in the most difficult places. Discover how our fleet of EXPLORER iLi robots deliver comprehensive, high-accuracy data from any pipeline. Protect your most valuable assets without compromise. pipetelone.com 1 855-7 855-747-3835 47-3835 [email protected]

SETTING THE ST STANDARD ANDARD FOR ROBOTIC INLINE INSPECTION


HEADLINE, APROXIMATELY 70 CHARACTERS (2 LINES) WELDING & FABRICATION PRECISION lautecu sanihilicae nulpa se et il id quid utaeptios evelitio verum volQUALITY • SERVICE •DEPENDABILITY oreroviti comnis dolorum liquam, ut aut ut quodici enimos cum que nate molende For allrfereste your Pipe natem Fabrication, sit vel eum Pipe voluptat Support, eumPipe faceria Clamp, volest and liscipicta ASME vendebis vendeb Pressure is Vessel repudae repudae needs. volest, utati utatiis is non non rem eserumq eserumque ue dolut dolut aut volorae cum et as sequasitio s equasitiorr maximus et fuga. Ab ilis mil modio occ umet ulpa doluptat. Agnit que dolorem nonsed quid enis et eatection resciet quam, velis im excea cus mil imus, ommoluptae ommoluptae doloresed ulpa quisquia pe veliquis inulluptur, inulluptu r, occulpa vendae sequi id ute sim qui od et ullesti oreicturit ut et deliti dignam, unti nusda que alistio et ut voluptatati idemolu ptistibeat eture in resserum qui nobitibus expero est, sed ut et, int officiet quibuscid elessequost, cusandaepero quis ea dolut disquia sperum aut as am nonsequia abore volorita cus magnatquatin essunt, culpa volupta verferovidel et alitae dolore velicient, nime nulparit latatur sequi blaccum eni dolo este volupta spidunt spidunt estibus. as sus qui alignateni renitis di ant. Hitam hil ide di occabo. Faccus corero ese mintion sendem veles molorata sapicimi, ipsa poreiur? Ur aut exceaquatur? Ulpa pratem et, odici nonessunt volorunt ipsapero exceribus eos etus sinture ea consequ atiurecabo. Et restian iHitam hil ide di occabo. Faccus as sus qui alignateni renitis di ant. Hitam hil ide di occabo. Faccus

PHOTO OR GRAPHIC


Two line caption Giatus quunt omnis re, ommoditet lab inihicae. Ximus, et quas debis

CONTACT INFORMATION CONTACT Address INFORMATION Phone Sweetwater Lane, Houston, TX 10002 Fax 281-252-0151, Toll free: 877-252-0152 Email281-252-8151 Fax: Website www.weweld.com

Precision Welding & Fabrication

• ASME Pressure Vessels Buy Direct from the Fabricator and save on your Pipe Clamps a nd Supports. • Pipe Fabrication • Stainless And Alloy Alloy Fabrication Fabrication • Structural Steel Steel Fabrication Fabrication Send your quotes to [email protected] or call today at 281-252-0151 • Cross- Overs, Overs, Platforms And Visit us at www.weweld.c w ww.weweld.com om Caged Ladders Precision Welding & Fabrication • Hydro-Testing 10002 Sweetwater Lane, Houston, TX 77037 • Field Measuring Phone: 281.252.0151 Toll Free: 877.252.0152 Fax: 281.252.8151 [email protected] john@wew eld.com www.weweld.com • Plate Rolling 

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CAPABILITIES GUIDE

POLYGUARD UNROLLS LATEST INNOVATION: RD-6® UVO OVERCOAT With forward thinking at its core, Polyguard Products has announced the introduction of RD-6 ® UVO overcoat. This is a single component, low VOC UV resistant, water-based liquid coating that is highly resistant to the damaging effects of harmful UV light rays. This new overcoat is used to protect Polyguard’s highly effective and popular RD-6® anti-corrosion coating from UV rays when it’s used for above ground pipeline field joint girth welds, valves, fittings, and FBE coated pipe. Polyguard conducted in-depth research and saw that direct exposure to sunlight could result in degradation of the RD-6 product. The result was adding this new product to ensure maximum stability. stability. This is an environmentally friendly, moisture resistant product that has excellent adhesion characteristics resulting in fast touch, drying and cure times. Although designed designed for RD-6 the RD-6 UVO overcoat can be applied over multiple coating types such as FBE or other epoxies. Founded in 1953, Polyguard Products specializes in products which protect surfaces and structures structures from moisture, water, water, or other undesired substances. Polyguard is an industry leader in the production self-adhesive protective protec tive coatings coatings for engineering engineering and and construction. construction. Polyguard Polyguard is also a 100% employee-owned ESOP with 25 consecutive years of sales growth.

CONTACT INFORMATION

JC Cody 214-515-5000 469-867-0611 [email protected] www.polyguard.com

‘Non-Shielding’ Corrosion Control Coatings for the Pipeline Industry

RD-6

®

Coating System

• Non-shielding in case of coating disbond and water ingress • Superior adhesion/lower elongation elongation means superior soil stress resistance

Polyguard.com www.Polyguard www. .com

Polyguard’s RD-6 has been used in the North American rehab and girth weld market since 1988. The RD-6 differentiates itself through its speed, simplicity, and proven performance record.

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| 81

Flow Assurance Because the flow must go on

to the build-up b uild-up of water, gas condensate, c ondensate, waxes, paraffi ns,

T

asphaltines, scales, hydrates, black dust. As these liquids

facility. In order to achieve this,

Maintaining production is crucial for the operators of oil and gas pipelines. Over time, changes in composition can lead

he primary objective of Flow Assurance is to economically optimize the transport of fluids

from the reservoir to the production

and solids accumulate, they can reduce flow — and in the

detailed and authentic inspection

worst cases block blo ck the pipeline. pip eline. For effi ciency and integrit integrity y

data is essential — and inspection

management, they must be removed. ROSEN has years of

success relies on analytical planning.

experience in the development and deployment of tools that

By drawing on existing tracking data,

help operators to effectively clean their pipelines. Our worldleading Flow Assurance service focusses on operational

ROSEN calculates the tool behavior that can be expected in gas, liquid, slurry, and multiphase lines. This allows for

challenges. By modelling steady-state and dynamic flow

recommendations on the optimization

behaviour, we can predict the volume and distribution of

of the tool velocity.

liquids and solids, design the appropriate tools to remove these in a controlled manner, and model the performance of the tools in the flow to ensure that the cleaning activity will not result in production problems.

For a successful pipeline inspection, cleaning is mandatory. ROSEN determines accurate surge and liquid volumes on the basis of data from previous inspections so that a correct and effi cient tool operation op eration is ensured ens ured for future inspection and cleaning runs. Furthermore, ROSEN gives advice on adequate cleaning cycles to make inspections and inventory runs as smooth as possible. One major cause for irregular flow is corrosion. Therefore, effective corrosion control and management is most vital in order to maintain ideal transport conditions within pipelines. ROSEN applies industry-standard corrosion models that are integrated in more extensive flow calculations, such as DeWaard, Milliams, NORSOK, and TOLC IFE models. To keep future corrosion in pipelines to a minimum, ROSEN assists customers with prioritizing their need of asset inspections and optimizing inhibitor-inject inhibit or-injection ion rates and efficiency.

www.rosen-group.com


STEP-KO STEP-K O PRODUCTS LLC, - WHERE QUALITY AND AFFORDABILITY MEET For nearly two decades Step-Ko Products LLC, has become a leader in the manufacturing of products for Cathodic Cathodic Protection. Centrally located in Broussard, Louisiana Step-Ko Products manufactures and stocks many different styles of Flange Isolation Kits with most ready for same day shipping. Our Flange Isolation Kits range from ½’’ to 144’’ that meets all ANSI and API specifications. Custom gaskets and special sizing are available upon request. This includes our critical service gasket called the Assureaseal™ Assureaseal™ SSC which i s a perfect solution to your severe service needs. Here at Step-Ko we also stock a large inventory of AssureaKote™ Poly Coated U-bolts in sizes ½’’ through 48’’. These poly coated u-bolts come bagged with four nuts, a neoprene support pad and are boxed up

ready for a speedy delivery. Paired with our AssureaPad™ a special blended thermo thermo plastic half round pad Step-Ko can get you moving. moving. At our warehouse in Broussard, Louisiana we also carry a new line of Monolithic Insulating Joints that are now in stock from sizes 2’’ thru 24’’ ANSI 600#. The Assureastop™ Assureastop™ is the way to go for a maintenance free, money saving solution for all industries. Step-Ko also offers a variety of tapes and liquid coatings as well as other pipeline products. These include pipeline markers for oil and gas, sewage and water lines as well as plastic pipe caps, plastic flange protectors and stainless steel as well. Looking for a better priced alternative, choose Step-Ko where quality and affordability meet.

STEP-KO PRODUCTS –

WHERE QUALITY AND AFFORDABILITY MEET

·PROTECT THE PIPELINE· WITH THE LEADER IN CORROSION

PROTECTION

Flange Isolation Gasket Kits Critical Service Gaskets Monolithic Insulating Joints Poly Coated U-Bolts and Thermo Pads Heat Shrink Sleeves and Liquid Coatings Various Pipeline Tapes and Fillers

IT ALL STARTS @

WWW.STEPKO.COM 84

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P.O. Box 81396 Lafayette, Louisiana 70598 Ph. 337.837.4141 Email: [email protected] SPONSORED CONTENT

CAPABILITIES GUIDE

Making Pigs Squeal Since 1984

Our transmitters emit the strongest signal in the industry, so it is easier to locate your pig or determine the time of its passing. With a full range of transmitter diameter sizes and mounting options for any type pig that accompany numerous signal receiver options, Pipeline Inspection Company should be your first stop for successful pigging operations.

APPLICATIONS • Mainline Transmission • Gathering Lines • Subsea Lines • Municipal Gas • Water and Wastewater • Refining and the Process Industries

Pipeline Inspection Company Phone : (713) 681-5837 Email : sales@picltd. [email protected] com www.picltd.com Visit our website for complete details or call for a brochure. SPONSORED CONTENT

SPY SP Y® Field Pro Proven Reliable 60 Years Under the Most Extreme Conditions Below zero or insane heat conditions, over under and across some of the world’s most difficult terrain, for decades Pipeline Inspection Company has understood the rigors of pipeline construction. Our SPY® Holiday Detectors have been buried, dropped from great heights, run over and even submerged during the course of pipeline holiday detection operations worldwide. When your project takes you to the extremes, rely on the SPY ® Holiday Detector from Pipeline Inspection Company.

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SPONSORED CONTENT

Egypt: The Next Natural Gas Hotspot By Nick Cunningham

T

he Eastern Mediterranean is becoming a major source of natural gas production, and Egypt is at the center of this emerging gas hub. In February, Noble Energy and its partners reached an agreement with the Egyptian company Dolphinus Holdings to sell gas from offshore Israel to Egypt, a deal that could jumpstart a much wider cam paign to develop natural gas in the Eastern Mediterranean. The deal is politically risky for Egypt, where dealings with Israel have historically been taboo. Nevertheless, after years of halting progress, the agreement is bolstering the region’s bid to transform itself into a sizable source of gas production, and potentially, exports. Israel has been trying to develop the large gas deposits in the Eastern Mediterranean for more than a decade, with some success and some setbacks. Noble Energy leads a team that discovered two very large gas fields is Israeli waters, bringing some production online in recent years. But the com pany is still stil l trying to scale up development. de velopment. Regulatory challenges from Israel forced the consortium to sell off stakes in the fields a few years ago over fears of concentrated control in the hands of just a few companies. The uncertainty delayed development, although Noble is pressing on. Meanwhile, Eni fast-tracked the development of the Zohr gas field in Egyptian waters, the largest discovery ever recorded in the Eastern Mediterranean. That field came online late last year and Egyptian officials believe it will be crucial to closing the country’s energy gap. But the more recent deal that will see Noble ship gas to Egypt could spark more aggressive development development of gas in the region. Wood Mackenzie said that the agreement could be pivotal in paving the way for more deals. “An initial deal had to be done to breathe confidence into the market,” WoodMac analyst Bas Percival told the WSJ. Egypt has some idled LNG export capacity, and collecting gas from the Eastern Mediterranean – both in Egypt and in Israel – and routing the gas through Egyptian LNG export terminals could mean a new source of LNG for the global market. The Wall Wall Street Journal reports that Royal Dutch Shell is in talks with investors in both

Egypt and Israel to help supply the export ing in Cypriot waters in February due to facility, which Shell owns. No deal has been its non-recognition of the Greek Cypriot announced yet, but the WSJ reports that government. Meanwhile territory disputes Shell is considering a $30 billion 15-year between Israel and Lebanon Leb anon could throw up plan to purchase gas from fields in Israeli new hurdles. But the thaw between Israel and Cypriot waters, then liquefy the gas and and Egypt is hard to overstate. export it through its facility in Egypt. Still, the route for Israeli gas to Egypt is Shell and Eni sit on LNG export facilities, unclear. The gas could be moved from Israel but gas production in Egypt went into steep through Jordan to Egypt, although that route decline several years ago due to price controls and lower investment from international com- has been subjected to attacks from militants in panies. panie s. Now Now,, with with gas supply on the rise, those the Sinai. The companies could also build an offshore pipeline that runs from the gas field facilities could be called upon once again. Meanwhile, the region received another to Egypt, although that could also prove costly. But with the proliferation of discoveries, jolt when when Eni and Total Total announced announced yet another gas discovery in the Eastern Mediterranean the increase in production from both Israel in February, although this time it was located and Egypt, and an emerging export option off the coast of Cyprus. The “Calypso 1” in Egypt, the Eastern Mediterranean could well suggests an extension of the “Zohr like” develop into a significant gas hub and source play,, Eni said in a statement, referring to its of gas exports. Wood Mackenzie estimates play enormous Egyptian gas field. Separately, Eni that the Eastern Mediterranean is home to signed deals with Lebanon to explore off the 125 tcf of natural gas. P&GJ country’s coast. Antipathy between governments in the Nick Cunningham is a freelance writer region could deter drilling. Turkish war- on oil and gas, renewable energy, climate ships reportedly stopped Eni from drill- change, energy policy and geopolitics. www.pgjonline.com

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Closer Look at Flammability, Inerting of Complex Hydrocarbon Mixtures

Husssein

Maxa

By Tarig Hussein and Daniel Maxa, University of Chemistry and Technology in Prague, and Martin Stukbauer, CEPS

I

n the lifetime of oil and gas pipelines there are numerous events that could pose the potential of an explosion hazard, with commissioning, maintenance, replacement, as well as decommissioning and abandonment serving as common examples. In case of air purging, flammable mixtures are created in pipelines in an uncontrolled manner. The first part of this article is dedicated to a revision of basic flammability and inerting principles. princi ples. Based Based on this back backgroun ground, d, applications of mobile nitrogen unit technology are described in the second part. The technology has been proven to increase safety com pared to air purg purging, ing, while simulta simultaneous neously ly maintaining high operational flexibility.

Flammability Limits Flammable gases and vapors can ignite and cause an explosion if mixed with adequate amounts of oxidizer, and a source of sufficient ignition energy is present. A flammable mixture is formed when the com bustible substance concentration reaches the interval between the lower flammability limit (LFL) and the upper flammability limit (UFL). Below LFL the mixture contains too little fuel to ignite. It is too lean. Above UFL the mixture contains too much fuel (too little oxidizer) to ignite. It is too rich. When inert gas is added, LFL slightly increases and UFL decreases steeply. Thus, the flammable range gets narrower due to a (corresponding) decrease of the oxidizer content. Ultimately, after reaching a certain threshold oxidizer concentration, LFL and UFL converge to a single point. With the further addition of inert gas any mixture is non-flammable after ignition, independently independen tly of the combustible substance concentration. The threshold oxidizer concentration is called “limiting oxygen concentration” (LOC), since oxygen (in air) is the most commonly occurring oxidizer. LOC refers to oxygen concentration in a ternary mixture of a combustible substance, substance, inert gas and oxygen. Values of LOC for multiple substances are available in corresponding standards 88

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[1-4] – and literature [5-7]. There is also a property called “limiting air concentration” (LAC), which expresses LOC as equivalent concentration of air in the mixture. To represent composition of fuel-oxidizer-inert gas mixtures as well as to assess purging purg ing scen scenarios arios a triang triangular ular diagra diagram m is commonly used. An example (Figure 1) for natural gas-oxygen-nitrogen mixtures. Mixing air with natural gas yields mixtures represented by the “Air line.” Mixtures created by mixing air, natural gas and additional nitrogen are on the right side of the air line. Flammability limits as well as LOC depend on temperature, pressure and com position of the mixture constituents. With increasing temperature and pressure, the flammability region expands. LFL and LOC decrease and UFL increases. The influence of composition is, however, more complex, because composition of the fuel, oxidizer and inert gas come into play. Air is, with some simplification, a mix-

ture of nitrogen (79% vol.) and oxygen (21% vol.). Due to i ts availability and abundance nitrogen is a commonly used inert gas, although other materials such as carbon dioxide or steam might also be used. Flammability parameters of pure hydrocarbons are well-documented in the respective standards [2-4] and literature5,6. Nevertheles Never theless, s, in the oil and gas pipeli pipeline ne industry the flammable substances are usually natural gas, crude oil or petroleum products – more or less complicated hydrocarbon mixtures. This implies the published data on pure hydro hydrocarbo carbons ns are are not not directly directly applic applicable able to assess the flammability of such mixtures reliably. Experiments would be the most reliable way to obtain the flammability data, but this approach is often time-taking and costly. To perform simple estimations, mixing rule formulas based on known properties of pure hydrocarbon constituents have been proposed by many authors [6, 8–10]. The most commonly used formula is the Le

Figure 1: Trian Triangular gular composition diagram includes flammability paramete parameters. rs.

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Air Purging

Figure 2: CEPS 2: CEPS nitrogen unit set-up at a crude oil pipeline terminal in Latvia

As a readily available and cheap material, air is often used for pipeline purging. Air purging can can be illustrated (Figure 1) by following the air line from the top apex, representing a pure combustible substance, down to the intersection with the oxygen axis, representing air composition. Conversely, air purging into service can be represented by following the airline from the air point

of the propellant and the pipeline’s geometry defects and deviations. In addition to that, some propellant might pass around the pig discs (loose) bolts. Therefore, mixing zones with potentially flammable mixtures might still occur close to the pig. Second, in the case of displacement of flammable liquids or NGL-rich1 gas, residual liquid film remains on the pipe walls. The liquid evaporates into the purging air, forming potentially flammable mixtures along the pipeline while phase equilibrium is being established. In the latter case, a water flush of the pipeline can be performed prior to purging, but it is associated with subseque subsequent nt dis posal of large quantities quantities of oil-contaminated oil-contaminated water. Hence, it is almost always impractical and inconvenient.

Inert Gas Purging To mitigate the flammability hazard, air is usually replaced with inert gas – typically nitrogen. The idea behind this approach is to eliminate the presence of oxygen such that no flammable mixture can be created regardless of the combustible substance concentration. LOC is a key parameter to assess the Figure 3: Transportation 3: Transportation of CEPS nitrogen technology equipment to an off-road job site in Croatia safety of inerting operations. However, for to purge a 36-inch (DN 900) crude oil pipeline. practical application LOC value might not always be convenient, since the composition in the pipe depends on the dynamics of the non-ideal mixing during purging. It is desirable to express this threshold in terms of minimal purity of the purging inert gas, which is unable to form ignitable mixture with any amount the combustible substance. This property is called “in-service-oxygenconcentration (ISOC)” and is equivalent to “limiting oxidizer fraction” (LOF) defined in the ISO 10156: 2010 standard. When flammable gases or vapors are purged with a nitrogen-oxygen mixture with oxygen content equal to ISOC, the resulting composition changes along the yellow line in Figure 1, which does not intersect the flammable mixture region. This applies to Figure 4: CEPS 4: CEPS nitrogen unit equipment at a job site in Slovakia during the purging of an 18-inch both purging in and out of service. ISOC (DN 450) crude oil pipeline. can be determined based on the known LOC and LFL according to the equation 2. Chatelier mixing rule for LFL estimation, up to the top apex. From the diagram, it see equation (1) where ci is molar (or voluis obvious that in both cases formation of metric) concentration (% mol. or vol.) and flammable mixtures is inevitable. LFLi is a lower flammability limit (% mol. This somewhat dangerous approach has LFL slightly increases with the addition or vol.) of an i-th flammable component in been improved by using a pig keeping air of nitrogen. As noted by Figure 1, the most the mixture. and the combustible substance separated. accurate ISOC value would be obtained by The pig is propelled by the purging gas using the LFL determined at the LOC point while displacing the original content of composition. However, this value is not the pipeline and eliminating mixing of air frequent in literature, especially for hydroWhen using literature data or theoretical and the combustible substance at the same carbon mixtures. Thus, value of LFL in air estimations, it is always important to compare time. Even though this is a much safer might be used as a simplification while yieldthe experimental or design conditions to the method, a few complications arise anyway. ing slightly more conservative ISOC results. target process conditions. Neglecting this step First, the pig’s sealing discs are not entirely So, is it not possible to switch to using air may result in dangerous misinterpretations. tight at all times due to the over-pressure for purging out of service instead of purging 90

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with inert gas or mixture the whole time? The answer is potentially yes, but only for gas pipelines. During purging, the flammable region could be avoided in two steps, producing non-flammable fuel-inert mixture at first and eventually purging the mixture with air. The fuel concentration at which further dilution with air would not produce flammable mixtures is called “out-of-service fuel concentration” (OSFC). However, the above mentioned procedure cannot be applied to pipeline pipe liness carr carrying ying flamm flammable able liqu liquids. ids. The residual film on the pipe walls after the dis placem pla cement ent of of liquids liquids is is a source source of flamma flammable ble hydrocarbons evaporating into the purging gas over time. Hence, using air is not inherently safe at any point of the operation. The described purging parameters generally do not include any safety margins but remain on the operator’s or the subcontractor’s subcontractor ’s consideration. Recommended values can be found in NFPA2 and AGA7 documents. The purging pur ging expertis expertisee and saf safety ety is also included included in know-how and internal standards of many responsible pipeline operators, consultants or subcontractors such as CEPS a.s. Further comprehensive information on pipeline purging can be found in the literature.7,9

Nitrogen Technology For smaller scale operations compressed nitrogen in steel cylinders is used. For larger scale projects nitrogen is often transported by tank trucks in a liquid state and needs to be evaporated before before used for purging. This operation is expensive and complicated due to logistics and supply chain continuity. However, progress has been made in the form of mobile units producing nitrogen-rich gas from air directly on site. This solution brings bri ngs flexibil flexibility ity,, es espe pecia cially lly co conc ncern erning ing tim time, e, off-road, and remote locations accessibility and operation control. This ensures continuous uninterrupted operation not limited by a size of the nitrogen storage tank, since nitrogen is produc pro duced ed fro from m the the surr surrou oundi nding ng air air.. Figure 2. Company CEPS has developed and successfully operates such mobile units. The whole self-powered technology has been fitted into a 20-foot ISO container and can be transported by off-road trucks (Figure 3, 4). The main operation parameters are summarized in Table 1. Optimal operation parameters are generally set based on working conditions; specifically, the purity of produced nitrogen is adjusted according to an ISOC assessment. CEPS built a nitrogen unit prototype in 2011 and launched commercial purging services in 2012. Since then the technology has been bee n succes successful sfully ly employ employed ed in many many projec projects ts in various kinds of environments. The projects required safe purging in and out of service of natural gas, diesel and crude oil pipelines

in the Czech Republic, Slovakia, Lithuania, Latvia, Hungary, Belarus, Croatia and Poland (Figures 2-5). With regard to safety and efficiency of the purging activities, a comprehensive set of

Parameter

Value

Max. pressure (bar), (psig)

25 (362.6)

Residual oxygen concentration (% vol.)

1-10

Nitrogen purity (% vol.)

90-99

Max. production flowrate (Nm 3 /h), Dew point (°C), (°F)

(scf/h)

1200 (44 797.8) 797.8) < -40 (-40); typically 65 (-85)

Table 1: Main operation parameters of a mobile nitrogen unit

Figure 5: A CEPS nitrogen unit loaded on a trailer truck while purging a 40-inch (DN 1000) natural gas pipeline in Poland.

guidelines based on research of has been acquired over the years. The research activities were conducted in cooperation with the Technical Institute of Fire Protection and the Department of Petroleum Technology and Alternative Fuels at the University of Chemistry and Technology in Prague. The acquired know-how contributes to safe, yet cost-efficient settings of the mobile units.

Conclusion With regard to the potential hazard of pipeline purging, it is not inherently safe to use air, especially when flammable liquids are involved. Therefore, inert gas purging solutions is preferred. However, it is not always practical to use tank trucks with liquid nitrogen (or other inert gas). Mobile nitrogen units come as a safe answer to the problem of offroad accessibility and operational flexibility whenever the demand comes. P&GJ SOURCES:

[1] National Fire Protection Association. NFPA 69: Standard on Explosion Prevention Systems. Quincy, Massachusetts: National Fire Protection Association. Association. 2002 [2] National Fire Protection Association. NFPA 56: Standard for Fire and Explosion Prevention During Cleaning and Purging of Flammable Gas Piping Systems. Quincy, Massachusetts: National Fire Protection Association. 2012 [3] ISO. ISO 10156:2010 Gases and gas mixtures -Determination of fire potential and oxidizing ability for the selection of cylinder valve outlets. 2010 [4] Czech Office for Standards Metrology and Testing. CSN EN 1839 ed. 2: Determination of explosion limits and the limiting oxygen concentration (LOC) for flammable gases and vapours.Prague: Czech Office

for Standards Metrology and Testing. 2017 [5] Molnarne, Maria, Thomas Schendler and Volkmar Schröder. Safety Characteristic Data Vol.2: Explosion Regions of Gas Mixtures. Germany: BAM Bundesanstalt für Materialforschung und-prüfung, 2008. ISBN 978-3-8650 978-3-86509-856-6. 9-856-6. [6] Zabetakis, Michael George. Flammability characteristics of combustible gases and vapors. Washington: U.S. Bureau of Mines. 1965. [7] American Gas Association. Purging Principles & Practice. 2001. [8] Le Chatelier, Henri and O. Boudouard. On the flammable limits of gas mixtures. Process Safety Progress [online], 24(1), 3–5. Available Available at: doi:10.1002 doi:10.1002// prs.10062 [9] Crowl, Daniel A. Understanding Explosions. Explosions. New York, USA: John Wiley & Sons, Inc., 2010. ISBN 9780-470-92528-7. [10] Zhao, Fuman. Inert Gas Dilution Effect on the Flammability Limits of Hydrocarbon Mixtures. 2011. Texas A&M University.

Authors: Tarig Hussein is a junior engineer in oil and gas downstream EPC business and holds a master’s degree in chemistry and technology of fuels and environment from the University of Chemistry and Technology, Prague. Daniel Maxa is a senior lecturer and researcher at the University of Chemistry and Technology Technology in Prague. He holds a Ph.D. degree in petroleum processing and fuels productio pro duction n technologie technologies. s. Martin Stukbauer is is a technology development manager in CEPS a.s. with more than 15 years of experience in the pipeline industry. He holds a master’s degree in chemistry and gaseous fuels technology technology.. www.pgjonline.com

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WHAT’S NE NEW W in Products & Services

Honeywell Honeywell is offering hands-free, wearable connected plant technology that allows workers to more efficiently accomplish their tasks in the field. The Skills Insight Intelligent Wearables Wearables feature a head-mounted visual display that responds to voice

and brings live data, documents, work procedures and health and safety information into view. It combines the RealWear HMT-1Z1™ hands-free wearable computer with Honeywell’s Movilizer platform, an industry leading, cloud-based workflow solution, to support field service operations in hazardous locations. The wearables offer operator task automation, video capture and geo-localization, navigation and asset visualization. www www.honeywell.com .honeywell.com

Siemens Siemens has partnered with Newgate Instruments to introduce the JT400 Multivariable Gas Transmitter (MVG), an ultra-low power device. The ultra-low power performance combined with accuracy delivers a product custom-tailored for midstream and upstream gas production. The JT400 MVG offers drop in compatibility via BSAP, Enron Modbus and ROC compatible protocols. It comes standard with Class I Division I, Group C, D, explosion-proof UL/CUL as well as intuitive menu operation with live trending in real time. Additionally, the JT400 offers DP measurement accuracy of 0.035% or URL, and its sensors remain accurate to 0.1% up to 133% of URL even when over-pressured. Power consumption of the device is less than 4mW, with static pressure reference accuracy of 0.035% of URL. www.usa.siemens.com

an LCD graphic display. In three-wire mode, a backlight is available for viewing in low-light environments. The sensor is cast aluminum and designed for flammable environments with a temperature range of -25º C to +55º C. www.larsonelectronics.com

Andax

Polyguard Products introduced the RD-6® UVO overcoat, a single component, low VOC UV resistant, water-based liquid coating that protects Polyguard’s RD-6® anti-corrosion coating from damaging UV light rays when used for above-ground pipeline field joint girth welds, valves, fitfi ttings, and FBE coated pipe. RD-6 UVO is environmentally friendly and moistureresistant with excellent adhesion characteristics, resulting in fast touch, drying and cure times. Although designed for RD-6, the overcoat also can be applied over multiple coating types, such as FBE or other epoxies. www.polyguard.com

Andax released the Xtreme Shell® Pipe Flange Containment System, a patented, reusable, hard-containment shell designed to enclose a pipe flange, manifold or any other leak point. The drain hose diverts the leak to a closed container, thereby reducing the potential danger of accidents or injuries caused by spills around equipment and walkways and eliminates the mess and ground contamination. A leak can be fixed on planned maintenance schedules. The optional Andax Remote Monitoring System can save time by eliminating the need to visually monitor remote locations. Fluid levels can be monitored 24/7 from a smart phone or compu computer, ter, and inst ant aler alerts ts and notifications can be delivered via text message or e-mail. www.andax.com

Larson Electronics

Matrox

Larson Electronics released an explosion-proof hydrocarbon gas sensor with a Class I, Division 1 and 2 (Groups B, C, D) rating for combustible environments. The device is used to test and monitor levels of toxic gas in the air. The EXP-SNR-TG-EC-ITS-ALG-HC200 is configured to uncover hydrocarbon vapors with a detection range of 0-200 ppm. Equi Equipped pped wit with h a sensor, ampl amplifi ifier er and memory module, the compact unit offers non-digital, analog output (4-20 mA output range). An integral sensor holder keeps the device stable during use. For seamless monitoring, the explosion proof hydrocarbon sensor features

Matrox® Imaging is introducing series of updates to the Matrox Supersight Solo high-performance computing (HPC) platform, including a new system host board (SHB) that improves computing performance. The platfo pla tform rm was des design igned ed to sim simpli plify fy sys system tem configuration, allowing original equipment manufacturers (OEMs) and integrators to use Matrox frame grabbers in a validated PC from a single vendor. Within this lifecycle-managed platfo pla tform, rm, co compo mpone nents nts are se selec lected ted to en ensur suree consistent long-term availability, so that OEMs can maximize return on original investment while delivering continuous product offerings. Matrox Supersight Solo features a new chassis to optimize compute density, with space

Polyguard Products

for up to 13 full-length, full-height PCIe® 2.0 board bo ardss to su suit it a wid widee range range of ima image ge-ac -acqui quisisition requirements. www.matrox.com

Ardco Ardco’s next-generation articulating multi purpose purp ose truc truck k (AMT (AMT)) feat features ures a modu modular lar back-e bac k-end nd pla platfor tform m that off offers ers the flex flexibil ibility ity to customize the vehicle. The AMT accepts a wide array of standard and customizable attachments. Available configurations include a bare chassis, dump bed, flatbed, water tank, fuel tank, service and lube station, utility bed,, pers bed personn onnel el carr carrier ier,, pipe trailer, trailer, drill and custom solutions. Multiple tire choices are available – tractor, construction, terra or sand. Powered by a 250-hp Cummins QSB6.7 Tier 4 Final diesel engine, the AMT 600 model features selectable 4- or 6-wheel-drive and offers a maximum payload of 45,000 pounds. The AMT 400 model has a 200-hp Cummins Tier 4 engine, offers 2- or 4-wheel drive, and provide prov idess a max max payloa payload d of 28,00 28,000 0 pounds pounds for for hauling. www.ardcomfg.com

Liftomatic Liftomatic Material Handling introduced the Ergo-PWPL-750 powered drum handling transport, a self-contained unit that engages, lifts, lowers and moves all steel, plastic and fiber drums. The equipment incorporates power pow er-driv drivee forw forward ard and reve reverse rse,, as wel welll as power-lift and -lower features for moving drums quickly. Varying weight capacities are available between 650 and 1,000 pounds. As part of Liftomatic’s Ergo-Matic line, the unit is equipped with programmable controls. Additional features include regenerative braking, available in straddle leg or fully counter-balanced versions, as well as EE and spark-resistant ratings. www.liftomatic.com P&GJ www.pgjonline.com

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TECHNOTES Product Development

Chinese Pipeline Selects Rotork ELB for Increased Line Break Safety The Rotork Electronic Line Break (ELB) is a self-contained system that combines pipeline pressure monitoring with intelligent valve control. It continuously monitors pipeline pressure dynamics dynamics to provide early detection of pipeline breaks and initiate automatic valve actuator movement to a pre-selected emergency emergency position. In one recent contract, Rotork GO (gasover-oil) pipeline actuators have been fitted with ELB units for line break monitoring and protection on remotely installed valves on a natural gas pipeline in China. The ELBs allow the operator to monitor the running condition of the gas pipeline and the open/closed status of the valves. The immediate reporting of a line break by an ELB will enable the operat or to swiftly close the appropriate valves and isolate the problem. The ELB is contained in a compact, environmentally sealed and explosion-proof housing that can be mounted on the actuator or remotely. Valve actuator control – selectable as fail close, fail open or stay put – is based on rate-of-drop (RoD) and rate-ofrise (RoR) of the pipeline pressure as well as high- and low-pressure limits. A remote process shut down (PSD) input with the option to override all functions is also available to drive the valve to the predetermined fail position. The ELB also provides an array of pro-

grammable alarm and alert indications and has an extensive range of features that can be configured to meet end users’ specific requirements. These include up to six remote inputs and four configurable solenoid outputs, partial stroke testing (PST) and Modbus® network connectivity. Setting menus displayed on the large HMI window are the focus for non-intrusive programming and commissioning using Rotork IQ intelligent electric actuation technology. In normal mode the LCD display indicates valve position. The same window also displays visual indication of status, alarms, event, trend and operation logs and diagnostic data. P&GJ

Platform Simulates Pipeline Network Elsyca V-PIMS is a graphical simulation platform for the integrity managemen managementt of pipeline networks with respect to external corrosion. The platform simulates and visualizes the CP health status of the entire network based on known design information. Correlating the simulation results with measured field data at test stations allows tracing anomalies in the CP operation, adapting rectifier currents for optimum protection, as well as analyzing and monitoring time-bound effects. The platform supports pipeline operators in complying with prescribed governmental requirements, such as the Dutch norm NTA NT A 8000 and US ASME B31.8S. , with respect to integrity management and risk management. managemen t. Correlation between surveyed “as-is” status and simulated “to-be” status enables monitoring of the condition of the pipeline network. The overall visualization of the network’s CP performance allows prioritization of preventive activities, while

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modifications and extensions to the network can be verified in advance. Key features include links with existing GIS databases and cartography systems, graphical visualization of pipeline network with color coding of CP health status and a post-processing environment for “what-if” analyses. P&GJ

New Frack Pump Reduces Maintenance Costs

Texas-based Weir Oil & Gas said its SPM® QEM 3000 Frac Pump continues to yield unsurpassed results and savings in the field as it looks and performs like new after 3,200 hours of field-proven use in extreme conditions in the winter months in the Duvernay and Montney Shale Play in Alberta, Canada. The SPM® QEM 3000 is expected to extend maintenance cycles by a factor of three, the company said, as compared to what operators are achieving in similar service conditions currently. Weir said these enhancements dramatically affect bottom lines, expanding traditional pump lifespan to improve uptime and productivity, while reducing maintenance and cost of ownership by at least 17%. The SPM® QEM 3000 was designed to withstand the most punishing pressure pumping operations, including continuous duty at a sustained maximum 275,000-pound rod load. In the Duvernay and Montney formations, the pump operated 16-18 hours per day in temperatures averaging 20-23 degrees Fahrenheit at a frack pressure of 10,50013,000 psi, average rod load of 206,250 to 233,750 psi with a 5-inch plunger and a flow rate of 264 to 343 gallons per minute. Roller bearings looked new after 3,200hours and shell bearings had considerable life remaining, Weir said. Other wear parts that would normally require replacement, such as guide sleeves, showed insignificant wear and did not require replacement. Moreover, the onboard filtration system delivered clean oil to enhance bearing life through optimized control. While the traditional frack pump development process typically tests up to 1 million cycles, Weir completed an endurance test of its beta SPM® QEM 3000 in its Fort Worth Research & Development Center lasting three times longer than other pumps in the company’s history. A Calgary-based customer has operated SPM® QEM 3000 pumps that have completed more than 10 million field cycles (about 1,700 hours) without any signs of fatigue to the main components, Weir said. P&GJ

TECHNOTES Product Development

Allseas Touches Down with Sonardyne Dual-Gyrousbls on Lorelay Stinger Offshore pipeline installation and subsea construction Allseas is taking advantage of the operational benefits available from Sonardyne International’s GyroUSBL acoustic positioning technology, following an order for two systems for its 236-meterlay vessel, Lorelay. Used in conjunction with a Ranger 2 ultra-short baseline (USBL) topside that also formed part of the order, the GyroUSBL transceivers will be installed on the end of the Lorelay’s stinger to acoustically track a remotely operated vehicle (ROV) deployed to ensure a pipe is accurately touching down in the permitted corridor. USBL transceivers are routinely deployed through the hull or over-the-side of a vessel, enabling targets to be tracked below, to the side and far behind. However, on a large dynamic positioned (DP) pipelay vessel such as the Lorelay, a transceiver cannot reliably “see” through the thruster wash created at the rear, so touchdown monitoring operations are often conducted by an ROV operating from a survey vessel (equipped with its own USBL system) following on behind. With a stinger-mounted GyroUSBL, there is an alternative. The unit combines a 6G HPT transceiver (either 5,000 or 7,000 Model) and Lodestar attitude and heading

reference system in the same assembly and is supplied pre-calibrated to eliminate the mechanical alignment errors seen in conventional USBL setups. These features allow an acoustic transceiver to be sited well away from noise interference, even on a dynamic structure such as a stinger, and deliver outstanding positioning performance. It also means that a pipelay vessel is able to employ its own ROV to carry out touchdown monitoring, allowing the accompanying survey vessel to get on with another task, or eliminating the need for it altogether altogether.. Mounting a GyroUSBL on a stinger is now a widely adopted practice among

pipelay vessel operators, operators, with the technique having first appeared on the market in 2013. The Lorelay will be third vessel in the Allseas fleet to be equipped in this way, with systems already in operation on the Pioneering Spirit and Solitaire. Alan MacDonald, of Sonardyne in Aberdeen said, “Locating a transceiver on the stinger is a great solution for ensuring that vessel noise disruption is rejected. The time-saving features of GyroUSBL results in reduced operational costs with the ability for users t o move it from vessel to vessel with minimal downtime while maintaining the highest levels of positioning performance.” P&GJ

Instrument Simplifies Flow Data Control in Oil and Gas Operations Field technicians, SCADA personnel and managers across oil and gas industry sectors can more easily generate, manage and inter pret flow data with a new flow computer that incorporates the functionality of a smart multi-variable transmitter in the same unit. The Thermo Scientific AutoXP flow computer is built for use in the harshest environments of midstream, downstream and upstream operations for both gas and liquid applications. The instrument allows operators to acquire accurate flow data from a variety of primary devices. Additionally, users can transfer primary variables such as differential pressure, static pressure and temperature data to remote devices. The instrument can also be networked into existing systems via an onboard Ethernet port. To simplify upgrading and need for maintenance, it is comprised of only four main hardware components. “Adding the smart multivariable transmitter functionality to the flow computer gives customers greater control and connectivity than was possible with two separate instruments,” said Ben Zhou, vice president

and general manager, environmental and process monitoring for Thermo Fisher. Fisher. Additional features include: � Bluetooth connectivity, connectivity, allowing users to access the instrument without exposure to hazardous materials � Infrared sensors, which enable menu operation without removal of the end cap to maintain safe operation � Compatibili ty with the Thermo Scientific AutoCONFIG software platform, which incorporates i ncorporates updated standards for hydrocarbon measurement calculations � Compliance with Class I, Division 1 hazardous location requirements. Certifications and compliances for the AutoXP Gas and Liquid Flow Computer include CSA/C-US Class I, Div 1, Groups B, C, D; ambient temperature range of -40° C to +85° C (-40° F to +185 °F), temperature code T6 (-40° C to 75° C) T5 (-40° C to 85° C) EN 61326-1: 2013 (industrial criteria); FCC 47 CFR, Part 15, Subpart B; ICES 003: 2016; with measurement Canada pending. P&GJ www.pgjonline.com

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BUSINESS Personnel Changes, Association News, Mergers & Aquisitions

Names in the News

Troy Construction CEO David Dacus was named Pipeliner of the Year by the Pipeliners Association of Houston. A longtime supporter who has twice served as president of the association, Dacus has Dacus overseen an aggressive ex pansion of Tro Troy y Construction since taking the reins of the family-owned company in 1986. With three primary offices in Texas and Georgia, the pipeline construction and maintenance company has more than 25 satellite offices and over 2,000 employees. The Williams Companies appointed Nancy K. Buese as an independent director on its board board,, filling a vacancy created by the retirement of Janice Stoney. Buese is executive vice president and chief finanBuese cial officer for Newmont Mining Corporation. She previously held executive positions at MPLX, a publicly traded midstream company, and MarkWest Energy Partners prior to its acquisition by MPLX. With Buese’s Buese’s appointment, the WilWilliams board consists of 11 members, 10 of whom are independent. ComEd President and CEO Anne Pramaggiore has been promoted to senior executive vice president and CEO of Exelon Utilities. She replaces Denis P. O’Brien, who will serve as adviser until his retirement Pramagglore at the end of 2019. Pramaggiore, a 20-year veteran of ComEd ComEd,, will over over-see six local electric and gas utilities. Lilis Energy, an exploration and development company operating in the Permian Basin of West Texas and Southeastern New Mexico, appointed Nicholas Steinsberger to its Board of Directors. He is a petroleum engineer with 31 years of experience. Pipetech, the independent process system integrity specialist, named Frank Andersen as general manager for Scandinavia. Anderson brings more than 10 years oil and gas experience to the company Andersen and will be based at the firm’s Stavanger hub. He joins the company from GS-Hydro Norge AS, where he was was the business business develdevelopment manager. Goodnight Midstream hired of Andrejka 96

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Bernatova as its chief financial officer. officer. Previously, she served as executive vice president and CFO of Core Midstream. Prior to that, Bernatova was vice president of Finance and Investor Relations at PennTex Midstream Partners. Michael J. Russell has been appointed to Optium Cyber Systems Board of Advisors, where he will oversee the development of the company’s cybersecurity platform for the petroleum industry. He has 40 years experience in the oil and gas sector and is chairmanship of the American Petroleum Institute-Houston Chapter Chapter.. Weiler Abrasives Group promoted Jason Conner to the position of vice president of sales for the U.S. and Canada. Conner joined Weiler Weiler in 2012 as a national accounts manager and was promoted to direcConnor tor of national accounts in 2015 after managing a significant portion of business with Weiler channel partners. partners. Rob Hausler has been hired as executive vice president of JLT Specialty USA, where he will advise on midstream and other energy sectors, while managing accounts and developing business. Based in Houston, he was previously with Marsh. Amplify Energy appointed Kenneth Mariani to serve as president and CEO. He previously previousl y served as the president of EnerVest and vice president of operations for Energy Corporation of America. Well services company Key Energy President and CEO Robert Drummond resigned from his role as CEO to pursue another op portunity.. He will continue portunity with his current responsi bilities during an interim Drummond period and remain on Key’s Board of Directors. Anadarko Petroleum named Mitch Ingram as executive vice president of International, Deepwater & Exploration. The com pany also announced Ernie Leyendecker, executive vice president of Exploration is retiring after more than 30 years in the oil and natural gas industry. Thomas E. Blaser, senior vice president and chief financial officer of W.R. Grace & Co., resigned from the company to pursue other interests. The company has retained an executive search firm Blaser and begun a formal search for his replacement.

David Lamont, CEO of energy services company Proserv, Proserv, is stepping down and will be replaced replaced by David Currie, who previously held positions as CEO of JDR Cable Systems and U.K. president for Aker Solutions. The American Council of Engineering Companies of Michigan (ACEC/M) selected Sean J. Kelley, of The Mannik & Smith Group, as its 2018-2019 president. Kelley has been employed in the Michigan Kelley engineering consulting industry for his entire 32-year career. He is a senior vice president and principal for his 300-plus person firm, l eading its downtown Detroit office. Oil services company Three60 Energy appointed Walter Thain as CEO, North Sea. Thain has 28 years in the oil and gas industry, having previo pre vious usly ly work worked ed for for Petro Petro-fac in the United Kingdom and UAE, most recently as Thain managing director, West for Engineering & Production Services. Resolute Energy Corporation appointed three new outside directors: Joseph Citarrella, managing principal of Monarch AlterAlternative Capital LP; Wilkie Colyer, principal of Goff Capital; and Robert Raymond, founding member and portfolio manager of RR Advisors. As a result of the appointments, the Board will now have 11 directors. Nathan Leslie has been appointed to chief sales officer at pipeline inspection company NDT Global. He joined the company in 2014 and has over a decade of experience in the oil and gas industry. Leslie Royale Energy appointed Board Director Rod Eson as CEO in a move that took effect immediately. Prior to accepting the position, he served as the CEO of Foothill Energy, a California-focused company he founded in 2004. Steven Shepard has been named director of Product Management for Ridgid in Elyria, Ohio. He will manage development of new products, and lead global new product development and growth stratShepard egies for the company’s hand,, tubing and pipe fabrication tools divihand sion. Shepard previously worked at Stanley Black & Decker. Continental Resources selected Shelly

BUSINESS Personnel Changes, Association News, Mergers & Aquisitions

Lambertz to the Board as a Class II director. She replaces James L. Gallogly who resigned in order to focus on his duties as the upcoming president of the University of Oklahoma. Enservco appointed Kevin C. Kersting to the new position of chief operating officer. Prior to joining the company, Kersting held several senior positions at CAP Logistics, which provides transportation services for heavy industry.

Energy services company Proserv opened its new Centre of Excellence in Great Yarmouth’ Yarmouth’ss Beacon Park in the United Kingdom. Developer Great Yarmouth Borough Council, together with New Anglia LEP and key stakeholders, joined Proserv at the 65,000-square-foot facility. It will feature 25% additional manufacturing space and a yard area. There is also room to add an 20,000 square feet of The newly opened Proserv Centre of Excellence. workshop space.

Companies in the News

The 10,000th machine delivered to its destination.

Michels Corporation received the 10,000th machine assembled and delivered by Caterpillar Hydraulic Excavator Facility in Victoria, Texas. According to Cat equipment dealer PipeLine Machinery International (PLM), the new 336F Hydraulic Excavator was presen pre sen ted to mai mainli nline ne pip pipeli eline ne con contra tracto cto r Michels in a ceremony on May 16, with guests and representatives of the companies in attendance. Shell Midstream Partners entered into a purchase and sale agreement to acquire Shell’s ownership interest in Amberjack Pipeline Company LLC. The pipeline transports 300,000 bpd, expected to increase to about 400,000 bpd by the end of 2019. Oilfield services company Danos was named the winner of a Silver Stevie Award in the “Best Newsletter or House Organ/ Publication – Online/Electronic” category in the 16th Annual American Business Awards. Danos’ internal weekly e-newsletter, The Pipeline – Keeping Employees Connected, was launched in 2015 for the company’ss 1,800 employees company’ employees worldwide. In 2017, The Pipeline averaged 7,447 unique page views per month. Krohne opened its state-of-the-art flow and level instrument manufacturing and calibration facility in Beverly, Mass. The headquarters will produce new and existing flow and level products, while continuing to serve as the main distribution hub to North American markets for all other products. Administration, sales, service and marketing, and a new training center will also be located in Beverly.

3 Bear Delaware Operating-NM launched a binding open season for volume commitments and acreage dedications to support construction of a new crude oil gathering and transportation system. The Hat Mesa System will gather crude oil from origination points in Lea County, N.M. WhiteWater Midstream announced transportation and interconnect agreements for its Delaware Basin Agua Blanca pipeline, a joint venture between WhiteWater and WPX Energy. Targa affiliate MarkWest Energy Partners will join as joint venture partners in the Agua Blanca pipeline, and WhiteWater entered into long-term transportation service agreements with two premier Delaware Basin producers in Cul berson County, Texas. Bioscience company Amyris’ subsidiary Novvi and Chevron Products Company said the two companies will develop renewable base oil technologies. Terms were not disclosed. Novvi produces a range of lubricant applications to the global market.

Associations in the News The Pipeliners Association of Houston awarded more than $700,000 in scholarships to college-bound students at its June meeting and elected Patrick Lamb as 201819 president. Lamb, who serves as senior vice president of Business Development at Murphy Energy Group, presented an award of appreciation to outgoing association President Danny Seal, senior project manager at Williams. Education/ Research in the News Rice University is offering a new master’s degree in energy data management in the coming school year. The Wiess School of Natural Sciences’ Department of Earth, Environmental and Planetary Sciences opened enrollment for fall 2018 and spring 2019 in its graduate program in subsurface geoscience. Rice faculty have collaborated with leading Houston oil and gas companies to develop a program for students to become data-enabled geoscientists.

Southwest Research Institute (SwRI) was awarded two contracts, totaling $1.2 million, from the U.S. Department of Energy to advance turbine technology for power plants. SwRI will develop a supercritical carbon dioxide (sCO2), coal syngas or natural gas-fired oxy-fuel turbine. It will also develop a modular, combined-cycle power system. Both projects should be completed in December 2019.

Obituaries Calvin Paul Evans, 88, died May 11, after a brief illness. He had a long career in the pipeline industry, in dustry, eventually working working his way up to executive positions and establishing his own company, Evans Pipeline Equipment in 1971. In 1985, Evans Pipeline merged with CRC Pipeline International, and Evans became chairman of CRC-Evans Pipeline International. He became an honorary mem ber of Pipe Line Contractors Association in 1996 and was a driving force behind the PLCA Scholarship Foundation. He is survived by his wife, Sylvia; sons Falkner (Linda) and Marc; and grandchildren Stephen and Joanna (Erik Lundberg). Mark Osadchuk, 83, a veteran of the pipeline industry, died die d April 12, peacefully at home. He invented the innovative Ozzie’s Ozzie’s Pipeline Padder in 1989 and founded a num ber of companies. Osadchuk helped form Central Pipeline and Cable Co. in 1965 and remained as president until 1967, when the company was was liquidated and organized as Natural Pipeline Co., based in Lakeville, Minn. In 1980, he formed Southeast Pipeline Contractors Inc., which became one of the largest mainline pipeline contractors in the United States. He is sur vived by his wife, Vera; their two children and spouses Velma Velma (Osadchuk) and an d Bob Hope of Scottsdale, Ariz., and Dwayne and Tina Osadchuk, of Scottsdale; and their two grandchildren and spouses, Amanda (Osadchuk) and Craig Ciliberti, of Scottsdale, and Nicholas and Alisha Osadchuk of Oak Creek, Colo. P&GJ www.pgjonline.com

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ADVERTISER’S INDEX Index provided as a courtesy to readers. While every effort is made to compile accurate listings, publisher assumes no responsibility for errors. Above Ground Markers.com LLC, www.AboveGroundMarker.com www.AboveGroundMarker.com.............. 104 Airport Windsock Corp., www.airportwindsocks.com ..................................... 104 American Petroleum Institute, www.API.org/ICPprograms.......................... 44-45 Armor Plate Inc., www.armorplateinc.com ........................................................... 35 Arnett & Burgess Pipeliners Ltd., www.abpipeliners.com............................... www.abpipeliners.com............................... 109 Badlands Security Group, www.badlandssecuritygroup.com www.badlandssecuritygroup.com........................ 109 Baker Hughes, a GE company, www.engagerecip.com www.engagerecip.com ................................. 107 Bishop Lifting Products, www.lifting.com ........................................................... 102 BKW, www.bkwinc.com ............................................................................... 100, 109 Brad Bean, www.b3pe.com www.b3pe.com ................................................................................. 100 Brandt Equipment Solutions, www.brandt.ca....................................................... 27 Burns & McDonnell, www.burnsmcd.com/PGJNaturally www.burnsmcd.com/PGJNaturally ............................. 46-47 CCI Pipeline Systems, www.ccipipe.com www.ccipipe.com .......................................................... 107 CDI Control Devices, Inc., www.piggin www.pigging.com g.com ...................................................... 68 Coastal Corrosion Control Inc, www.coastalcorrosio www.coastalcorrosion.com n.com ........................... 103 Commercial Resins, www.commercialresins.com www.commercialresins.com ........................................... 104 CRC-Evans Pipeline International, www.CRC-Evans.com ........................ 17 17,, IBC Cross Country Infrastructure, www.CrossCountryIS.com www.CrossCountryIS.com ............................... 104 Darby Equipment Company, www.darbyequip.com ...........................................33 Davis Corp. (D.C.I.) , www.davcorpipelinerollers.com www.davcorpipelinerollers.com...................................... 106 Denso North America, www.densona.com .................................................... 48-49 DMI International, www.dmiintern www.dmiinternational.com ational.com ...................................................... 99 Dualco, www.dualco-inc.com............................................................................... 106 Dura-Bond Coating Inc., www.dura-bond.com www.dura-bond.com ...................................................... 9 E N R General Machining Company, www.ENRHotTap.com www.ENRHotTap.com ......................... 108 E-Z Line Pipe Support Co., Inc., www.EZLine.com............................................... 5 Elgin Separation Solutions , www.ElginSepar www.ElginSeparationSolutions.co ationSolutions.com m ................. 106 Enduro Pipeline Services, www.enduropls.com .................................... 50-51, BC Energy Web Atlas, www.EnergyWebAtlas.com.................................................... www.EnergyWebAtlas.com.................................................... 43 FG Clean Wipes, www.FGCleanWipes.com www.FGCleanWipes.com/efusion /efusion ................................ 69, 108 Flow Management Devices LLC, w ww.oag-ps.com...................................... 52-53 Galvotec, www.galvotec.com ............................................................................... 104 GasPro Americas, www.GasProcessin www.GasProcessingConference.com gConference.com ................................. 26 Geo Corr, www.geocorr.com................................................................................ www.geocorr.com................................................................................ 109 H&M Shared Services, www.henkels.com .....................................................54-55 Harding Directional Drilling, www.hardingdrilling.com www.hardingdrilling.com..................................... ..................................... 100 Harsco, www.HarscoAXC.com ............................................................................... 11 Heaman Pipe Bending, Inc., www.heaman.com .............................................. 103 Heath Consultants, Inc., www.heathus.com ...................................................... 105 Inline Services, www.inlineservices.com ..............................................................70 John Deere Construction & Forestry Division, www.JohnDeere.com/pipeline www.JohnDeere.com/pipeline 3 Knapp Polly Pig, Inc., www.pollypig.co www.pollypig.com m.............................................................. 71 KS Energy Services, Inc., www.ksenergyservices.com www.ksenergyservices.com .................................. 103 Lane Trailer Manufacturing Manufacturing Co., www.lanetrailers.com ................................... 104 Laney Directional Drilling, www.laneydrilli www.laneydrilling.com ng.com ......................................... 56-57 Lift Technologies, Inc., www.lift technologiesin technologiesinc.com c.com....................................... 108 Magnetrol International, www.magnetr www.magnetrol.com ol.com ...................................................... 98 Meridien Energy, LLC, www.meridienenergy.com www.meridienenergy.com ...............................................23 MESA, www.mesaproducts.com www.mesaproducts.com .................................................................. 72, 107 Michels Corporation, www.michels.us/PushingLimits www.michels.us/PushingLimits ........................................ 15

Midwestern Contractors, www.midwesterncontractors.com/legacy www.midwesterncontractors.com/legacy ............. 103 Midwestern Manufacturing Co., www.sidebooms.co www.sidebooms.com m ......................................73 MPG Pipeline Contractors, www.mpg-plc.com ................................................. 101 N-SPEC/Coastal Chemical, www.coastalchem.com .................................... 58-59 NACE, www.nace.org/career www.nace.org/career-development -development .......................................................... 74 Opvantek, www.opvantek.com................................................................................75 Outlaw Padding Company Company,, www.outlawpaddin www.outlawpadding.com g.com..................................... 102 Pe Ben USA, www.pebenusa.com ...................................................................... 108 Pigs Unlimited International, Inc., www.pigsun www.pigsunlimited.com................................76 limited.com................................76 Pipe Spring LLC, www.laughlincompanies.net www.laughlincompanies.net .................................................... 78 Pipeline Data Services LLC, www.pipelinedataservices.com www.pipelinedataservices.com ........................ 103 Pipeline Drying International, www.pipelinedrying.com www.pipelinedrying.com .................................. 105 Pipeline Equipment Inc., www.pipelineequ www.pipelineequipment.com ipment.com.............................77, .............................77, 105 Pipeline Machinery International, www.plmcat.com............................................ 41 Pipeline Opportunities Conference, www.pipeline-opportunities.com.............25 Pipeline Pigging Products, Inc., www.pipepigs.com........................................ 102 Pipeline Technology Forum, www.pipelinetech www.pipelinetechforum.com forum.com ................................ 13 Pipesak Inc, w ww.pipesak.com........................................................................ 60-61 Pipetel Technology, Inc., www.pipetelon www.pipetelone.com e.com .................................................... 79 PLH Group Inc., www.plhgrou www.plhgroupinc.com pinc.com .......................................................... 62-63 Polyguard Products, Inc., ww w.polygu w.polyguard.com ard.com ...................................................81 Precision Welding & Fabrication, www.weweld.com ..........................................80 Pro Access Rentals, www.proaccessrentals.com ............................................ 106 Project Piping Solutions LLC, w ww.projectp ww.projectpipingsoluti ipingsolutions.com ons.com.................... 102 Proline Pipe Equipment, Equipment, www.proline-global.com ........................................... 102 Quanta Pipeline Services, www.QuantaServices.com ....................................... 82 Qarter Turn ACTUATION, ACTUATION, www.QT www.QTActuation.com Actuation.com................................................ 42 Rosen Swiss AG, www.rosen-group www.rosen-group.com .com ............................................................. 83 Rosen Swiss AG, www.rosen-group.com ............................................................IFC Rotork Controls, Inc., www.rotork.com............................................................ 64-65 SICK Inc., www.sick.com ........................................................................................... 7 Southern Gas Association, www.southerngas.org ........................................... 107 SPY Pipeline Inspection Company, www.picltd.com .......................................... 85 STATS STA TS Group, www.statgroup.com ........................................................................21 Steel Etc., www.steeletc.com www.steeletc.com ............................................................................... 100 Step-Ko Products, www.step-k www.step-ko.com o.com ..................................................................... 84 Subscription, Subscriptio n, www.pgjonline.com ....................................................................... 111 Triple Trip le D Bending, www.pipebending.com.......................................................... www.pipebending.com.......................................................... 102 Troy Tr oy Construction, Inc., www.troycon www.troyconstruction.com struction.com.......................................... .......................................... 105 U.S. Pipeline, Inc., www.uspipeline.com ............................................................... 19 United Piping Inc., www.unitedpi www.unitedpiping.us ping.us............................................................... 27 UniversalPegasus UniversalPegasu s International, www.universalpegasus.com ..........................40 Vermeer Corpoation, www.vermeer.com .............................................................. 86 Weamco, www.weamco.com ............................................................................... 106 Weldbend Corporation, www.weldbend.com ................................................. 66-67 Welker Flow Measurement Systems, www.wfmsinc.com .................................. 29 Wolseley Industrial Group, www.wolseleyindustrialgroup.com www.wolseleyindustrialgroup.com .........................37 Women’s Global Leadership Conference, www.WGLCon www.WGLConference.com ference.com...........89

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A Conversation with Kinder Morgan’s Tom Martin By Joe Hollier

T

om Martin serves as president of the Natural Gas Pipelines Group for Kinder Morgan, one of the largest energy infrastructure companies in North America. In this role, he is responsible for all commercial and operational activities of the Kinder Morgan Natural Gas Pipelines Group, which encompasses approximately 70,000 miles of natural gas transmission pipelines and gathering lines, plus storP&GJ: When

did you get involved in the oil and gas industry, and how did you end up in your current position at Kinder Morgan? Martin: I first got involved in the energy industry in the mid to late 1980s in the advent of natural gas transportation and marketing becoming an open access and unbundled marketplace.. It was an exciting and fascimarketplace nating time to grow up in the industry with so much change and opportunity opportunity.. I joined Kinder Morgan in 2003 and have worked in both intrastate intrastate and interstate interstate markets. As I have grown in my career, I have come to appreciate and be proud of the important role that pipeline infrastructure plays in the economic development of our country and improved quality of life for people.

Martin:

age, treating and processing facilities. Martin joined Kinder Morgan as vice president of Optimization and Storage in the Texas Texas Intrastate Pipeline Group in 2003. He was named president of the Texas Intrastate Pipeline Group in 2005 and assumed his current position in 2009. Martin has more than 25 years of commercial experience in the unregulated and regulated U. S. natural gas pipeline industry. He holds a bachelor’s degree in accounting from Texas A&M University and is a registered Certified Public Accountant.

At the federal level, the current Administration seems open to taking seriously legitimate safety and technology concerns as they develop regulations, but the imposition of tariffs on imported steel is problematic. Our other current concern is what happens with NAFTA. NAFTA. Mexico is a strong market for us; we deliver more than 70 percent of U.S. exports to Mexico.

approximately 2.5 million tons per year of LNG, which is equivalent to about 350 million cubic feet per day of natural gas. This project adds liquefaction and export capability to Southern LNG Company’s existing terminal at Elba Island in Georgia. It is supported by a 20-year contract with Shell.

P&GJ: Are you concerned there might be broader implications for Canada’s interP&GJ: The Permian Basin continues governmental squabbling over the Trans to be a prolific resource. What is Kinder Mountain expansion? How does this comMorgan doing there now, and is there an pare and contrast with U.S. state agencies opportunity or need for more pipeline taking actions that impede construction of expansions? FERC-approved projects? Martin: There is currently an enorMartin: It’s all fueled by the so-called mous need for additional pipeline transpor- “keep it in the ground” agenda. While I certation capacity in the Permian, and we are tainly respect that people have different opinworking on several expansion projects on ions about natural gas and oil, it would be better P&GJ: Has the growing anti-fossil fuel our existing NGPL (Natural Gas Pipeline if those opinions were better grounded in facts. movement changed how Kinder Morgan Company of America) and EPNG (El Paso Oil, natural gas, natural gas liquids and addresses stakeholders on new projects and Natural Gas) systems in order to help allevi petrochemicals petrochemica ls are the foundation of our expansions? ate some of the constraints. civilization. And I’m sure these protesters Martin: It has always been a priority We also are developing the Gulf Coast would be surprised to learn that while the to consult with a variety of stakeholders at Express Pipeline with joint-venture partners U.S. has increased its reliance on natural gasevery stage of a project. As pipeline proj- DCP Midstream and Targa Resources, in powered electricity electricity generation generation by 45% in the ects have increasingly become a target for response to the tremendous need for addi past decade, power-sector power-se ctor CO2 emissions the anti-fossil fuel movement, however, we tional takeaway capacity out of the Permian. have been engaging with stakeholders much Kinder Morgan will build and operate the have gone down 28% in the same period of earlier in the project planning process. $1.75 billion project, which is designed to time. Or that U.S. methane emissions from Each project is unique, but we typically transport up to 1.98 billion cubic feet per natural gas systems decreased over 15% have conversations with landowners, local, day of natural gas from the Permian Basin from 1990 to 2016, despite a 49% increase in state and federal officials, as well as regula- to growing markets on the Texas Gulf Coast. natural gas production over the same period. tory agencies, businesses, community orgaP&GJ: What are some of your interests nizations, indigenous groups, individuals or P&GJ: How is the Elba Liquefaction groups opposed to our project, and others. Project coming along, and when do you expect outside of work? Martin: I am from a large extended Our goal is to educate our stakeholders about to start exporting LNG from the facility? family that lives locally, so I am fortunate the need for the project, provide project Martin: Construction is currently under details, such as possible facility locations way at our Elba Liquefaction Project, and to be able to spend leisure time with them and construction timing, and to address any we are expecting initial service to begin and close friends on a regular basis. I also issues or questions they may have. in the third quarter of this year. year. The final enjoy traveling, reading, listening to music, units are scheduled to come online by mid- going to sporting events and being involved P&GJ:: Does the company have any concerns about pending regulations? 2019 to bring total liquefaction capacity to in the community. P&GJ

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