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March 2019

World Trends and Technology for Offshore Oil and Gas

SEISMIC VESSEL SURVEY

1903OFFC1-C5.indd 1 2/28/19 4:04 PM THE CHALLENGE IS OUT THERE.

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International Edition Volume 79, Number 3 Celebrating 60 Years of Trends, Tools, and Technology

• SEISMIC VESSEL MARKET UPDATE that traditionally have slowed down the process. The first deploy- Challenges remain for seismic survey vessel market ��20 ment will be in 2020 on the deepwater Liuhua subsea tieback in the While much of the offshore industry is slowly rebounding, the South China Sea. seismic vessel survey market continues to be challenging for those contractors that still remain active. And that list has become much • GEOLOGY & GEOPHYSICS smaller in the past few years. Companies have exited the market, Gabon offers wide-ranging blocks, improved terms in filed bankruptcy, and sold their fleets. latest license round ��29 Gabon is offering 35 blocks over wide-ranging water depths under • ASIA/PACIFIC the country’s 12th Offshore Licensing Round. Four geophysical con- Oscilay process speeds production, cuts cost of long- tractors have put together 3D and 2D seismic data-sets for would-be length umbilicals ��24 applicants, which have employed modern processing and imaging Aker Solutions has developed a method for manufacturing large methods that reveal potentially large oil and gas accumulations in power umbilicals that voids the frequent interruptions for splicing hitherto untested plays.

Offshore® (ISSN 0030-0608). Offshore is published 12 times a year, monthly, by PennWell® Corporation, 1421 S. Sheridan, Tulsa, OK 74112. Periodicals postage paid at Tulsa, OK 74112 and at additional mailing offices. SUBSCRIPTION PRICES: US $127.00 per year, Canada/Mexico $165.00 per year, All other countries $208.00 per year (Airmail delivery $292.00). Worldwide digital subscriptions: $76.00 per year. POSTMASTER: Send address corrections to Offshore, P.O. Box 47570, Plymouth, MN 55447. Offshore® is a registered trademark. © PennWell Corporation 2019. All rights reserved. Reproduction in whole or in part without permission is prohibited. We make portions of our subscriber list available to carefully screened companies that offer products and services that may be important for your work. If you do not want to receive those offers and/or information via direct mail, please let us know by contacting us at List Services Offshore, 1421 S. Sheridan Rd., Tulsa, OK, 74112. Printed in the USA. GST No. 126813153. Publications Mail Agreement no. 40612608.

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© 2019 Halliburton. All Rights Reserved. Inspired by the past.Leading intothefuture. years, we have as earnedourreputation “the execution company,” delivering unparalleled We’ve comealongway since1919. withasingleproductinsmalltownWhat started is safety, collaboration, competitiveness, creativity, reliability, andrespect. Together, we are committed tocontinuingourlegacyasoneofthemost well-respected energyservices now a global organization with more than 60,000 employeesnow aglobalorganizationwithmorethan60,000 aroundtheworld. For 100 customer service andinnovativecustomer service solutionstotheoilandgasindustry. Ourinspiration comes fromourpeople—pastandpresent—andthe values we for: stand integrity, INNOVATION. COLLABORATION. EXECUTION. companies intheworld aswe preparetoleadintothefuture. hal100.com 12/20/18 9:53AM Hallibur_OS_1901 1

© 2019 Halliburton. All Rights Reserved. 1903OFF01-05.indd 3 © 2019 Halliburton. All Rights Reserved. Inspired by the past.Leading intothefuture. years, we have as earnedourreputation “the execution company,” delivering unparalleled We’ve comealongway since1919. withasingleproductinsmalltownWhat started is safety, collaboration, competitiveness, creativity, reliability, andrespect. Together, we are committed tocontinuingourlegacyasoneofthemost well-respected energyservices now a global organization with more than 60,000 employeesnow aglobalorganizationwithmorethan60,000 aroundtheworld. For 100 customer service andinnovativecustomer service solutionstotheoilandgasindustry. Ourinspiration comes fromourpeople—pastandpresent—andthe values we for: stand integrity, INNOVATION. COLLABORATION. EXECUTION. companies intheworld aswe preparetoleadintothefuture. hal100.com 12/20/18 9:53AM 2/28/19 4:17 PM ᶁ CONTENTS

Volume 79, Number 3

Technology gains taking subsea COVER: While much of the offshore industry is slowly rebounding processing deeper, farther out ...... 44 from the downturn, the seismic vessel survey market continues to Since the release of the first Worldwide Sur- have its challenges. Yet work is picking up in some regions. Shearwater vey of Subsea Processing Technology poster GeoServices recently secured two North Sea seismic campaigns for its in Offshore in 2008, INTECSEA has mon- multi-purpose vessels WG Tasman (cover) and WG Cook. The surveys, which will be performed for Aker BP and Equinor, call for four new itored the status of the technologies and ocean bottom seismic surveys in the Norwegian North Sea starting this systems used on the seafloor to enhance summer. (Courtesy Shearwater GeoServices) reservoir recovery rates. The technologies continue to mature with each successful field development application. ENGINEERING, CONSTRUCTION, & INSTALLATION ᶁ Vessel-based decommissioning Decommissioning market advancing offshore the UK ...... 32 system offers economic Changing UK continental shelf dynamics offer an invaluable window of opportunity. With alternative ...... 47 decommissioning scheduled to occur over a longer timeline, the country can build on exist- Well decommissioning is traditionally

ing specialist skills and expertise. While decommissioning is occurring in other oil and gas

performed from drilling rigs due to the provinces around the world, a significant number of UKCS projects are substantial in scale perspective new a from complexity of operations and the available and technically complex.

technologies and methods, which often Employing best practices underpins FPSO include risers, divers, and explosives. But things see clients our help We project success ...... 35 increasingly, operators are looking to a Although the successful design and implementation of an FPSO on a project is a result of vessel-based approach to not only keep a multitude of decisions and tradeoffs for the operator, experience has proven that using decommissioning project costs down, but

lessons from past projects helps successful completion of current and future projects. also to reduce non-productive time and

safety risks to workers. ᶁ PRODUCTION OPERATIONS Eider bypass project extends lives ᶁ EQUIPMENT & ENGINEERING THINKING of North Sea fields ...... 38 Production optimization platform TURN YOUR Oil production from TAQA’s Eider platform in the UK northern North Sea had become offers enhanced uneconomic after nearly 30 years in service. However, by converting the facility to a new predictive failure analytics ...... 49 utility role, supplying power to other fields in the area, the company has ensured continued operations at these fields until well into the next decade. Crane adapted for deeper water wind farms ...... 50 ᶁ SUBSEA Industry advances ROV and AUV technologies ...... 41 Motion compensation technology improves decommissioning As the offshore oil and gas industry recovers, demand for remotely operated vehicles (ROV) operations ...... 52 autonomous underwater vehicles (AUV) increases. ROV and AUV manufacturers are re- AROUND sponding with new systems that maximize uptime. HWCG selects m-pipe for emergency well containment riser ...... 53

DEPARTMENTS Online ...... 6 Comment ...... 7 Data ...... 8 Global E&P ...... 9 Offshore Europe ...... 12 Gulf of Mexico...... 13 Subsea Systems ...... 14 Vessels, Rigs, & Surface Systems ...16 Drilling & Production...... 18 Offshore Wind Energy ...... 19 Business Briefs ...... 54 Beyond the Horizon ...... 56 41 Advertisers’ Index ...... C3

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from a new perspective new a from

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LATEST NEWS AVAILABLE AT OFFSHORE-MAG.COM VP AND GROUP PUBLISHING DIRECTOR Paul Westervelt [email protected] The latest news is posted daily for the offshore oil and gas industry covering tech- CHIEF EDITOR/ nology, companies, personnel moves, and products. CONFERENCES EDITORIAL DIRECTOR NEW ON-DEMAND WEBCAST David Paganie [email protected] MANAGING EDITOR Top Offshore Projects: Leading strategies in capital efficiency Bruce A. Beaubouef [email protected] After a prolonged market downturn, offshore field development projects are once EDITOR-EUROPE again moving toward first oil. Higher oil prices, cost reductions, technological Jeremy Beckman [email protected] breakthroughs and strategic engineering have enabled operators to sanction their ASSISTANT EDITOR Jessica Stump [email protected] deepwater developments. In this year’s “Top Offshore Projects” webcast, sponsored POSTER EDITOR by Bentley Systems, Calpipe Industries, LLC, and Wood, the Offshore editors select E. Kurt Albaugh, P.E. [email protected] the projects that have successfully been re-engineered and restructured to succeed EDITORIAL CREATIVE DIRECTOR in today’s marketplace, and will the describe the new technologies and engineering Jason Blair methods that have enabled these projects to move forward. PRODUCTION MANAGER https://www.offshore-mag.com/webcasts/offshore/2019/01/top-offshore-projects-leading- Shirley Gamboa [email protected] strategies-in-capital-efficiency.html MARKETING MANAGER Myla Lowrance [email protected] NEW MAPS, POSTERS, AND SURVEYS AUDIENCE DEVELOPMENT MANAGER • 2019 Worldwide Seismic Vessel Survey Emily Martin [email protected] • 2019 Worldwide Survey of Subsea Processing Technology Poster • OFFSHORE EVENTS 2019 Status of US Gulf of Mexico Deepwater Discoveries David Paganie (Houston) [email protected] • 2019 Gulf of Mexico Map Gail Killough (Houston) [email protected] • 2018 Environmental Drilling and Completion Fluids Survey • 2018 Worldwide Survey of Floating Production, Storage and Offloading Units • 2018 MWD/LWD Services Directory https://www.offshore-mag.com/maps-posters.html www.pennwell.com OFFSHORE NEW SUPPLEMENTS 1455 West Loop South, Suite 400, Houston, TX 77027 U.S.A. Hess Stampede Supplement Tel: (01) 713 621-9720 • Fax: (01) 713 963-6296 https://www.offshore-mag.com/content/dam/offshore/site-images/HESS_STAMPEDE_PDF_ www.offshore-mag.com FINAL.pdf National Ocean Industries Association Supplement CORPORATE OFFICERS https://www.offshore-mag.com/content/dam/offshore/print-articles/Volume-78/04/ PRESIDENT AND CHIEF EXECUTIVE OFFICER: OFF1805NOIASupp_Web.pdf Mark C. Wilmoth French Supplement EXECUTIVE VICE PRESIDENT, https://www.offshore-mag.com/content/dam/offshore/print-articles/Volume-78/04/ CORPORATE DEVELOPMENT AND STRATEGY: OFF1805FrenchSuppWeb.pdf Jayne A. Gilsinger NEW VIDEO WHITE PAPER CHIEF OPERATIONS OFFICER PENNWELL MEDIA: Robert Brighouse The Challenges of Maintaining Equipment on Offshore Platforms The operating environment of an offshore platform offers one of the toughest chal- SUBSCRIBER CUSTOMER SERVICE lenges to the maintenance engineer. Combined with the limited space and remote To start a free subscription, visit www.offshoresubscribe. com. Contact us for subscription questions, location of most offshore facilities, the task of delivering cost-effective, efficient and address changes and back issues durable equipment requires considerable expertise. With so many production OFFSHORE processes involving a multitude of pumps, turbines and motors, it is critical to have P.O. Box 47570 Plymouth, MN 55447 a well-developed asset management system to reduce the amount of reactive Tel: (800) 869-6882 • Fax: (866) 658-6156 maintenance on a platform. This white paper, sponsored by Sulzer, highlights po- International Callers: +1 512-982-4277 Email: [email protected] tential proactive solutions for prevention. https://www.offshore-mag.com/whitepapers/offshore/2019/04/the-challenges-of- CUSTOM PUBLISHING Roy Markum [email protected] maintaining-equipment-on-offshore-platforms.html Tel: (713) 963-6220 SUBMIT AN ARTICLE REPRINT SALES Rusty Vanderpool [email protected] Offshore magazine accepts editorial contributions. To submit an article, please review Tel: (918) 831-9144 the guidelines posted on our website by following this link. www.offshore-mag.com/index/about-us/article-submission.html

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1903OFF06-19.indd 6 2/28/19 4:22 PM COMMENT • Subsea sector benefiting from efficiencies, technology development

DAVID PAGANIE, CHIEF EDITOR

THE CONSENSUS VIEW of many industry is available inside this issue, and at offshore-mag.com/ analysts is that the subsea sector is leading the maps-posters. The accompanying article begins on page 44. offshore growth cycle, with tree orderbooks Another critical component of a subsea production system swelling to levels not seen in years as operators is the power umbilical which distributes power from the host take advantage of low costs. But this enthusiasm platform to seabed production and pumping systems. CNOOC is tempered by a supply chain that is still strug- has sanctioned the first commercial run of a new power um- gling to make ends meet. Nevertheless, the data bilical manufacturing method for a subsea tieback project in is encouraging. Operators ordered 286 subsea trees in 2018 – the the South China Sea, writes Jeremy Beckman, Offshore edi- highest total since 2013, according to Westwood. The firm tor-Europe. Aker Solutions’ Oscilay machine will produce the expects awards for up to 400 subsea trees this year, with a focus static sections of the Liuhua 16-2 power umbilicals, part of a on projects in Brazil and emerging deepwater markets in Guyana, package of more than 71.5 mi (115 km) of dynamic and static Mozambique, and Senegal. power umbilicals the company is supplying that will connect The improvement in the subsea market can be attributed to wells at the deepwater Liuhua 16-2, 20-2, and 21-2 gas-conden- project simplification and standardization, but it is also an sate fields to a new FPSO. ongoing commitment to technology development. Inside this The new process has been designed to address the challenges issue, Offshore reviews a selection of new and developing tech- presented by extreme tension loads on umbilicals during in- nologies that are enabling this subsea revival. stallation. An Aker Solutions team in Malaysia is leading the Offshore’s annual subsea poster insert, developed by INTEC- engineering for the Liuhua project, with a team in Mobile, Al- SEA and Kurt Albaugh, Offshore volunteer poster editor, looks abama, responsible for all production. Final delivery is scheduled at the evolution and application of subsea processing and for 2020. boosting systems. It also outlines the various partnerships and Jeremy’s full story begins on page 24. alliances that have emerged to bring the technology to market. Meanwhile, the uptick in subsea development should improve One relatively new technology that is being used in the field demand for ROVs and AUVs. Jessica Stump, Offshore assistant following a lengthy qualification process is subsea compression. editor, reviews the latest technology developments in this space. The poster details the two major operational compression One example is Flatfish, a resident subsea autonomous vehicle projects, Åsgard and Gullfaks South Brent. The early success of designed to perform subsea asset inspections. Shell awarded these two projects has led other operators to evaluate the Saipem a license to develop the technology which should be technology for their fields. qualified for commercial application by 2020. Pseudo dry gas systems, an alternative to compression, are Jessica’s report begins on page 41. emerging for long-distance tiebacks of 62 mi (100 km) long or While the subsea sector is improving, the subsurface seismic greater. This technology, adapted from surface applications, acquisition market continues to be challenging for those con- helps overcome the pressure losses due to gravitational effects tractors that remain active, writes Bruce Beaubouef, Offshore in long tiebacks and deep waters. managing editor. A number of seismic vessel operators over the Subsea water treatment is another technology that is ma- past few years have exited the market or were forced to file for turing through the technical readiness level process. It is also bankruptcy. Offshore has refreshed its seismic vessel survey, detailed and described on the poster. This emerging technology last published in 2015, to get a feel for the state of the market. can reduce space and equipment on the host topsides, eliminate Bruce’s seismic vessel report and survey begins on page 20. water injection flowlines and risers, and simplify the subsea hardware for the water injection system. The poster also chronicles the water-depth and tieback-length progressions of subsea boosting systems. As of Feb. 2019, the Shell-operated Stones facility holds the record for the deepest water depth (9,600 ft/2,927 m), and the Murphy-operated Dal- mation field holds the record for the longest tieback (22 mi/35 km). Both projects are in the US Gulf of Mexico. To respond to articles in Offshore, or to offer articles for publication, The “2019 Worldwide Survey of Subsea Processing” poster contact the editor by email ([email protected]).

MARCH 2019 OFFSHORE | WWW.OFFSHORE-MAG.COM 7

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Worldwide offshore rig WORLDWIDE OFFSHORE RIG COUNT AND UTILIZATION RATE count and utilization rate FEBRUARY 2017 – JANUARY 2019 The offshore rig market experienced mod- 1,000 100 est improvements across every category during January. The total number of jack- 900 90 ups, semis, and drillships under contract grew by two units to 432 rigs. However, 800 80 it has been at roughly this same level for several months now. Meanwhile, five more 700 70 rigs have been removed from the global fleet, taking the total supply down to 759. 600 60

As a result, rig utilization had a bump up to Number of rigs 57.0% from 56.3% in December. The num- 500 50

ber of rigs working experienced a similar Fleet utilization rate, % 400 40 increase, climbing from 398 units in De- cember to 402 in January. 300 30 – Justin Smith, Petrodata by IHS Markit Feb. Apr. Jun. Aug. Oct. Dec. Feb. Apr. Jun. Aug. Oct. Dec. 2017 2018 ‘19 Total utilization Total supply Total under contract Working Merakes sparks hope for Note: Rig types included are jackups, semis, and drillships long-delayed Indonesian Source: IHS Markit RigPoint projects The recent final investment decision (FID) INDONESIA FID VOLUMES 2010-2021 for the Eni-operated Merakes gas discovery 2,500 in Indonesia has set the ball rolling for get- Liquids Merakes Ande-Ande Lumut, ID ting projects sanctioned from the country’s Gas Donggi-Senoro LNG, ID Abadi LNG, ID long list of delayed projects. Others Indonesia Deep-water Development (IDD), ID Kasuri Block, ID Indonesia has Southeast Asia’s largest 2,000 FID count in forecast with 24 fields expected to be sanctioned within two years. The cumulative development costs for these 1,500 projects would be around $6.4 billion. Considering the decline in existing ma- Time, cost and safety efficient

ture fields in Indonesia and the growing do- Mmboe 1,000 mestic energy demand, developing these leakagetest solutions major projects is becoming a higher priority item as time passes. It will be interesting to see if some of the 500 long-delayed projects can come off the back burner with lower project costs and improved planning. The recent push from 0 the government and ministry regarding the 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 Merakes and other projects, the new prof- Source: IHS Markit RigPoint it-sharing scheme, and an improving price scenario imply more pending projects are likely to be sanctioned going forward. OFFSHORE RIG CONTRACT COUNT – Prateek Pandey, Senior Analyst, 70 Rystad Energy 60 KaMOS® Gaskets for sealing and surveillance KaMOS® Kammprofil Gasket Offshore rig contracting 50 momentum continues - the efficient solution for flanged connections to build 40 In January, 55 rig contracts were con- KaMOS® Gaskets verifies correct installation by pressure firmed, according to Evercore ISI’s latest 30 testing the ring room in flanges. “Offshore Rig Market Snapshot.” This is up 19 from a year ago for the fifth high-

Number of contracts 20 Selected references: est monthly total since 2014. With four of the top five monthly fixture counts taking BP, ExxonMobil, Total, Saipem, Shell, Hyundai, ConocoPhillips, place in the past 12 months, the analyst 10 Chevron, PTTEP, Halliburton, AMEC Paragon, Technip Offshore UK Ltd said, offshore rig contracting momentum is clearly building. If the YTD pace of activity 0 “KaMOS® Gaskets to be used, when having too many leakages in flanged connections...” extends through 2019, contracting activity Jan. Feb. Mar. Apr. May Jun. July Aug. Sept. Oct. Nov. Dec. is on track to increase another 27% in 2019 2014 2015 2016 2017 2018 2019 KaMOS® RTJ Gasket (+30% jackups, +20% floaters). Source: IHS-Petrodata, Evercore ISI Research P.O.Box 484, N-4291 Kopervik, Norway • Tel +47 52 84 43 40 • Fax +47 52 84 43 41 • [email protected] • www.kamos.no

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NORTH AMERICA and install a new gas compression platform at the Cassia com- BHP has committed $256 million for further drilling later this plex in the Columbus basin, 35 mi (57 km) southeast of Trinidad. year and studies on the deepwater Trion oilfield offshore Mexico. McDermott will fabricate the 8,928-ton (8,100-metric ton) top- Results from the recent 2DEL appraisal well reduced uncer- sides and the bridge that will link the structure to the existing tainties but another well will be needed to firm up volumes Cassia B platform at its yard in Altamira, Mexico. Trinidad ahead of a potential development. Offshore Fabrication Co. will provide the 3,747-ton (3,400-metric ◆ ◆ ◆ ton) jacket, to be installed in 223 ft (68 m) of water. The new Excelerate Energy and Equinor Energy have completed what Cassia C facility’s three turbine-driven compressors will receive is claimed to be the first ship-to-ship transfer of LNG offshore 1.2 bcf/d through new piping across the bridge connection, the Bahamas. This involved the floating storage and regasifica- returning the compressed gas to Cassia B for export. tion unit Exemplar and the LNG carrier Arctic Voyager while ◆ ◆ ◆ both were moored at Equinor’s South Riding Point storage and ExxonMobil and its partners have continued their run of suc- transshipment terminal. cesses in Guyana’s offshore Stabroek block. Wells on the Tilapia and Haimara prospects delivered respectively oil and gas-con- CARIBBEAN SEA/SOUTH AMERICA densate, with Tilapia-1 representing the fourth commercial oil Brazil, Guyana, and Mexico will continue to lead the way this find in the Turbot area. ExxonMobil now sees potential for at year in terms of high-impact exploration drilling, according to least five FPSOs on the block by 2025, producing more than Wood Mackenzie. The stand-out program will likely be on the 750,000 b/d combined. Petrobras-operated Peroba prospect in the presalt Santos basin ◆ ◆ ◆ off Brazil, where volumes could exceed 5 Bboe. The consultant Petrobras has started operations at the FPSO P-67 in the Lula also highlighted Tullow Oil’s upcoming well on the 200-MMboe Norte area, the ninth production platform on the BM-S-11 block Jethro structure well on the Orinduik block off Guyana. in the presalt Santos basin. The location is 161 mi (260 km) ◆ ◆ ◆ from the Rio de Janeiro state coast in 6,988 ft (2,130 m) water BP has commissioned McDermott International to construct depth. Up to 150,000 b/d of oil from nine production wells will

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Selected references: BP, ExxonMobil, Total, Saipem, Shell, Hyundai, ConocoPhillips, Chevron, PTTEP, Halliburton, AMEC Paragon, Technip Offshore UK Ltd “KaMOS® Gaskets to be used, when having too many leakages in flanged connections...”

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MARCH 2019 OFFSHORE | WWW.OFFSHORE-MAG.COM 9

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be offloaded to shuttle tankers, with associated gas sent through Sonangol will contribute two new ultra-deepwater 7th gener- the existing presalt subsea pipeline network. By year-end, Petro- ation vessels, Libongos and Quenguela, both under construction bras expects output from all the facilities on the Lula field to at DSME in South Korea. Seadrill will manage and operate all have reached 1 MMb/d. four drillships, initially over a five-year term. In the same basin, but closer to the coast, the company has ◆ ◆ ◆ contacted TechnipFMC to supply the rigid pipeline/riser net- Total has proven po- work for the presalt Mero-1 field development in 6,890 ft (2,100 tentially large vol- m) water depth, also installing the flexible risers and flowlines, umes of gas-con- steel tube umbilicals and other subsea equipment. MODEC, densate in the which is constructing the field’s FPSO Guanabara MV31, has Brulpadda prospect subcontracted Estaleiros do Brasil to fabricate and assemble off the southern the topsides process modules at the EBR shipyard in São José coast of South Afri- do Norte. The vessel is designed to process up to 180,000 b/d ca. The well, drilled of oil and 12 MMcm/d of gas. by the semisub Deepsea Stavanger WEST AFRICA on block 11B/12B in GeoPartners is collaborating the Outeniqua ba- with Sierra Leone’s Petro- sin, encountered leum Directorate on a new hydrocarbons in two 5,592-mi (9,000-km) 2D seis- separate intervals. It The Deepsea Stavanger drilled the mic survey to be acquired was the French ma- Brulpadda-1 well in the Outeniqua basin off over the country’s entire off- jor’s second attempt South Africa. (Courtesy Total) shore area. The resultant to drill, having had data will be made available to abandon its first shot in 2014 due to poor weather. to bidders for the country’s The company and its partners plan to follow up with a 3D 4th Offshore Petroleum Li- seismic survey and four more exploratory wells on the license. censing Round which is due Coverage to be provided by Brulpadda, thought to hold up to 1 Bboe, may have a ready this year’s 2D seismic survey to launch later this year. offshore Sierra Leone. (Courtesy market at PetroSA’s Mossel Bay onshore gas-liquids plant, 112 ◆ ◆ ◆ GeoPartners) mi (180 km) to the northwest. Results from the latest well on the Pecan field offshore Ghana and supplementary analysis MEDITERRANEAN SEA point to discovered resources of 450-550 MMboe across the BP has started gas production from the Fayoum and Giza fields Deepwater Tano Cape Three Points block. Pending the outcome in the West Nile Del- of two further planned appraisal wells, operator Aker Energy ta (WND conces- sees scope to increase the range to 600-1,000 MMboe, with other sion). Development targets on the block potentially included in an area-wide de- involved drilling velopment. Water depth at the Pecan-4A well location was 8,750 eight wells and in- ft (2,667 m). stalling associated The FPSO Kwame Nkrumah has successfully been rotated subsea infrastruc- to a new heading of 205° at the Jubilee field offshore Ghana. ture and pipelines, Operator Tullow Oil commissioned a remediation program with combined out- after detecting issues with the turret bearing system. Next year, put from the two a new catenary anchor leg mooring buoy is due to be put in fields eventually set place for offtake of the vessel’s produced oil. to reach 700 ◆ ◆ ◆ MMcf/d. Four fields Nigeria’s government has renewed the license for the offshore are now onstream in OML 113 concession by a further 20 years. Operator MX Oil is WND, with the fifth Location of the Fayoum and Giza fields in looking to step up production from the Aje field by drilling new – Raven – to follow the West Nile Delta concession. (Courtesy DEA Deutsche Erdoel) wells in the Cenonamian and Turonian intervals, eventually later this year. Total lifting output to 20,000 b/d of oil and 100 MMcf/d of gas. peak output will be 1.4 bcf/d, all contracted to Egypt’s domestic ◆ ◆ ◆ market. Seadrill and an affiliate of Angolan state oil company Sonangol ◆ ◆ ◆ have formed a new venture named Sonadrill. This will operate Tunisia’s Directorate General of Hydrocarbons has agreed to four drillships with a focus on opportunities offshore Ghana. renew Panoro Energy’s Sfax Offshore exploration permit. The

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Norwegian company and partner ETAP separate long-term agreements to supply LNG converted from the deepwater Golf- are working on a program of drilling and inho/Atum gas fields to India’s Bharat Gas Resources, Shell International Trading testing of the offshore Salloum West-1 Middle East, and Tokyo Gas/Centrica. The total volume contracted could reach up well, investigating a fault compartment to 5.6 MM metric tons/yr (6.17 MM tons). The partners plan to initially construct two updip of British Gas’ 1992 Salloum oil LNG trains onshore Mozambique with an annual capacity of 12.88 MM metric tons discovery. If successful, Salloum could (14.2 MM tons). A final investment decision on the project should follow by be developed fasttrack through nearby mid-year. infrastructure. ◆ ◆ ◆ Egyptian General Petroleum Corp. has reportedly awarded exploration rights to three promising concessions in the Med- iterranean Sea to various consortia under Egypt’s 2018 Bid Round. ExxonMobil, BP, IEOC (Eni), Total, Shell, and Petronas secured block 3 – North East El Amreyia and have agreed to drill two wells. BG (Shell) and Petronas were awarded block 4 – North Sidi Gaber and have pledged to acquire 579 sq mi (1,500 sq km) of 3D seismic and to drill one well. The same duo picked up block 6 – North El Fanar, where the program includes an 869-sq mi (2,250-sq km) seismic survey.

EASTERN EUROPE Black Sea Oil & Gas and its partners have decided to proceed with the $400-million Midia gas project in the Romanian sector of the Black Sea. They plan five production wells – four surface wells at the Ana field and one subsea well at the Doina field – with production from Doina heading through an 11-mi (18-km) subsea pipeline to a new unmanned production platform at Ana. From there, a new 78-mi (126-km) pipeline will transport the gas to a new 1 bcm/yr onshore treatment plant in Corbu, Constanta county, for onward delivery through the Romanian grid. GSP Offshore will construct, install and commission all the facilities. The same contractor has been working for Turkish gas distributor BOTAS drilling subsea storage wells and supervising construction of two fixed offshore platforms under Phase III of the Marmara natural gas storage extension project. These facilities should increase storage capacity from the present 2.84 bcm to 4.3 bcm.

EAST AFRICA Anadarko Petroleum and its partners in Area 1 offshore Mozambique have signed

1903OFF06-19.indd 11 Nylacast_OS_1903 1 1/25/192/28/19 10:04 4:22 PMAM JEREMY BECKMAN • OFFSHORE EUROPE LONDON

DOCK DEVELOPMENT TARGETS RIG STAYS tieback, Myers said. Other tie-in options may include Total’s PSW Group and Wergeland Holding have started construction Elgin-Franklin complex, which is closer, and BP’s ETAP hub to of a new drydock in western Norway to accommodate offshore the northwest. But CNOOC may prefer a standalone develop- drilling rigs and vessels. The facility in Gulen Industrial Harbor, ment. Rystad Energy said the results of this well will likely turn due to be completed in 2020, will be used for wide-ranging the area into an exploration hotspot over the next few years, programs related to inspection, repair, and maintenance. Po- building on the UK’s strong exploration drilling record since tentially the length could be extended by 50% to 300 m (984 ft): 2016. combined with a width of more than 100 m (328 ft) and a depth of 25 m (82 ft) this would be the largest facility of its kind in MORE TIEBACKS TO GJØA Europe, PSW claimed, with access to rigs and vessels from three Neptune Energy is looking to extend the life of the Gjøa field sides leading to shorter yard stays. semisubmersible platform in the North Sea via two further satellite developments, in addition to the ongoing Nova field tieback. It has submitted plans to develop the P1 segment on the northern part of the Gjøa field and the 2016 Duva (ex-Cara) discovery to the northeast, where it proposes one gas and two oil production wells connected to a four-slot subsea template in 360 m (1,181 ft) water depth. In both cases, production through the platform could begin in late 2020/early 2021, with peak combined output of 54,000 boe/d. Lundin Norway is the latest taker for TechnipFMC’s integrated engineering, procurement, construction, and installation (iEPCI) model. The company has appointed the contractor to manage the Luno II and Rolvsnes subsea development in the Utsira The new drydock under construction at Gulen Industrial Harbor. High region of the North Sea, supplying and installing subsea (Courtesy PSW Group) production systems, rigid flowlines, umbilicals, and flexible jumpers in 110 m (361 ft) of water. All will be tied back to the CNOOC FINDS BIG GAS AT THIRD ATTEMPT Edvard Grieg field platform. CNOOC’s recent Glengorm gas-condensate discovery could tempt others to test the surrounding play fairway in the UK TULIP GAS FIELD GOES LIVE central North Sea, according to various analysts. This was the Tulip Oil Netherlands has started production from Q10, its first company’s third attempt to drill the prospect on the P2215 li- operated gas field development in the Dutch North Sea, a year cense after technical issues halted both previous operations. after taking a final investment decision. Heerema Fabrication Borr Drilling’s harsh environment jackup Prospector 5 spud the Group supplied the unmanned platform, with Borr Drilling’s latest well toward the end of last year in 80 m (262 ft) of water on the way to a final depth of 5,056 m (16,588 ft), encountering 37 m (121 ft) of pay in an Upper Jurassic reservoir. Results were at the top end of expectations said CNOOC’s partner Total, suggesting close to 250 MMboe recoverable. Glengorm appears to be the UK’s largest offshore gas find since Maersk’s Culzean in 2008 said Wood Mackenzie and succeeded despite very high downhole temperatures and pressures. Another consultant, Westwood, added that this could be one of the sector’s top four discoveries of the past two decades, the others being Buzzard in the same region and the still un- developed Rosebank oil field west of Shetland. Westwood’s Dr Keith Myers pointed out that the geological setting – Upper Jurassic turbidites – has in the past proven to be variable in this area in terms of thickness and quality. Like other nearby HP/ The newly onstream Q10 field platform. (Courtesy Tulip Oil) HT structures, Glengorm is likely to be compartmentalized, he suggested. jackup Prospector-1 responsible for the five development wells. The partners plan follow-up appraisal work and have iden- Production heads to the TAQA-operated P15 platform via a tified other Jurassic prospects elsewhere on the block. As the new 42-km (26-mi) pipeline laid by Allseas. Tulip discovered Culzean field center, due onstream later this year, comes off Q10 (formerly known as A07A) in 2015 in shallow water, 20 km plateau in 2023, capacity could become available for a subsea (12.4 mi) from the central Dutch west coast.

12 WWW.OFFSHORE-MAG.COM | OFFSHORE MARCH 2019

1903OFF06-19.indd 12 2/28/19 4:22 PM BRUCE BEAUBOUEF HOUSTON GULF OF MEXICO •

BOEM DETAILS NEXT REGION-WIDE GULF OF MEXICO LEASE SALE The Bureau of Ocean Energy Management will offer 78 million acres in a region-wide lease sale this month. Lease Sale 252 will include all available unleased areas in federal waters of the Gulf of Mexico. The sale will include about 14,696 unleased blocks, located from 3 to 231 mi (5 to 372 km) offshore, in the Gulf ’s Western, Central and Eastern planning areas in water depths ranging from 9 to more than 11,115 ft (3 to 3,400 m). The sale, scheduled to be livestreamed from New Orleans, will be the fourth offshore sale under the 2017-2022 national outer continental shelf oil and gas leasing program. The Gulf of Mexico OCS, covering about 160 million acres, is estimated to contain about 48 Bbbl of undiscovered technically Ensco says that Apache has awarded the semisubmersible ENSCO 8503 a four-well contract for work in the Gulf of Mexico, recoverable oil and 141 tcf of undiscovered technically recoverable from June to August 2019. (Courtesy Ensco plc) gas, according to BOEM.

SENTINEL MIDSTREAM PROPOSES DEEPWATER CRUDE LLOG COMMISSIONS MCDERMOTT FOR STONEFLY OIL EXPORT FACILITY SUBSEA TIEBACK Sentinel Midstream has outlined its planned development of Texas LLOG Exploration Co., L.L.C. has awarded McDermott International GulfLink, a deepwater crude oil export terminal near Freeport, Inc. an EPCI contract for the Stonefly subsea tieback to the Ram Texas. Powell TLP in the deepwater Gulf of Mexico. The completed facility will be capable of fully loading very large Located about 140 mi (225 km) southeast of New Orleans in crude carriers, the company said. Viosca Knoll block 999, the Stonefly development calls for a two- Texas GulfLink will include an onshore terminal with up to 18 well subsea tieback to the Ram Powell platform via 60,000 ft 6-in. MMbbl of storage, a 42-in. offshore pipeline, and a manned offshore pipeline at water depths ranging from 3,300 to 4,100 ft (1,006 to platform to facilitate port operations with two catenary anchor 1,250 m). leg mooring single point mooring buoys. The company said pro- The scope of work includes project management, installation jected export loading rates will be up to 85,000 b/hr, with a nominal engineering, subsea structure and spoolbase stalk fabrication, and capacity of 1.2 MMb/d over the course of a calendar year. installation of the subsea infrastructure. McDermott will also design, Sentinel Midstream President and CEO Jeff Ballard said: “Texas fabricate, and install a steel catenary riser, a pipeline end manifold, GulfLink will provide the United States with an economical solution and two in-line sleds. to clear the over-supply barrels destined for the Gulf Coast. We Structure design and installation engineering began in January have compiled a team of industry leading professionals who possess in McDermott’s Houston office. The North Ocean 105 vessel is unique experience in construction and operations of deepwater expected to install the subsea infrastructure in 3Q 2019. ports and are well positioned to leverage that experience as prudent operators. GULFSLOPE UPDATES DRILLING AT TAU PROSPECT “Our team of seasoned professionals is committed to developing The Tau prospect well has drilled through about 7,000 ft (2,134 m) Texas GulfLink with a specific focus on exceeding industry stan- of salt where high pressures and hydrocarbons near the base of dards for safety and environmental protection.” salt were encountered and significant mud losses occurred, ac- Over the past year, the company developed Texas GulfLink in cording to operator GulfSlope Energy Inc. conjunction with multiple stakeholders, including federal, state, The company is currently tripping for a different drilling assembly and local agencies. The project has secured necessary commercial to clean out the existing wellbore and possibly run casing prior to support to justify the capital investment and is preparing its sub- drilling below salt. mission of a formal permit with the United States Maritime Ad- The Tau prospect well targets multiple Miocene sand levels ministration (MARAD). trapped against a well-defined, angled flank of the large salt struc- Project financing is being provided by Cresta Fund ture. The correlative target subsalt Miocene sand levels are oil Management. productive at the nearby subsalt Mahogany field. Cresta Managing Partner Chris Rozzell said: “We view the Tau is the first of eight drill-ready exploratory prospects that company’s value proposition, which provides a neutral infrastruc- the company intends to drill along the Louisiana outer continental ture solution without the inherent conflicts of affiliated marketing, shelf, targeting the subsalt Miocene play. as the best approach to support the interests of US producers and GulfSlope is the operator with a 20% working interest. Delek lead to the greatest outcome for all stakeholders.” GOM Investments LLC owns a 75% working interest and Texas South Energy Inc. owns a 5% working interest.

MARCH 2019 OFFSHORE | WWW.OFFSHORE-MAG.COM 13

1903OFF06-19.indd 13 2/28/19 4:22 PM JESSICA STUMP • SUBSEA SYSTEMS HOUSTON

JIP TO DEVELOP BEST PRACTICE ROV/AUV SYSTEM PROVES DOCKING CAPABILITY FOR TOP TENSION RISERS Saab Seaeye has successfully Connecting What’s Needed with What’s Next™ 2H Offshore has launched a joint industry project (JIP) with docked its iCON-based Saber- Anadarko, BP, and Shell to develop top tension riser (TTR) re- tooth AUV/ROV at a deepwa- assessment and life extension guidance. The main aims of ter docking station to receive TRACS (tensioned data transfer, assignment riser assessment for instructions, and battery continued service) charging. The company are to develop a road claims this is a breakthrough map for assessing is- for the offshore market, which sues related to fitness has been monitoring devel- for service of TTRs opments in remote residency and to provide rec- technologies because of the ommendations for potential operational and fi- mitigation of poten- nancial benefits. tial issues. During trials the 3,000-m The TRACS JIP aims to develop a road The Sabertooth ROV/AUV in tank The JIP will then map for assessing issues related to fitness (9,842-ft) water depth rated trials. (Courtesy Saab Seaeye) apply data from case for service of top tension risers and to Sabertooth, fitted with a Blue studies supplied by provide recommendations for mitigation of Logic 2kW charger/inductive potential issues. (Courtesy 2H Offshore) the participants to device, was able to dock in a safe and controlled manner, both validate the methodology and provide documented examples in the horizontal and vertical plane. for future guidance. Jan Siesjö, chief engineer at Saab Seaeye, Sweden, said the Currently, according to 2H Offshore, there is no single guide- vehicle was the only one available capable of hovering both in line in the US addressing in detail TTR reassessments and life ROV and AUV mode, and of undertaking long- term residency extension programs. operations in difficult to access locations. The JIP will adopt both Bureau of Safety and Environmental The Sabertooth can be based at a remote location docking Enforcement and API frameworks to pursue industry consensus station ready to be launched on pre-programmed or human-con- on the analysis and inspection data and documents needed for trolled missions, which include inspection, repair and mainte- assessing the potential for extended service life. nance, research tasks, and environmental monitoring. At the SOLVE YOUR Along the way it will address issues such as fatigue, corrosion docking station, tooling packages are stored, batteries recharged, and change of service, and will put together recommendations and data transferred via satellite or cable to shore. for mitigation measures for each issue, taking into account DECOMMISSIONING environmental and operational histories. SUBSEA LIFTING SYSTEM COMPLETES In addition, the JIP will examine the latest analysis, inspection PRE-TRIAL TESTS and monitoring tools to help deliver an accurate assessment Ecosse IP Ltd.’s latest CHALLENGES of equipment condition. subsea lifting prod- Sandeep Jesudasen, subsea riser engineering leader at BP, uct, the Ambient said: “As deepwater facilities age, the industry needs to look at Lifter, has completed continued service assessment and life extension to facilitate pre-trial tests in sustained safe production.” Buckie Harbor, northeast Scotland. TECHNIPFMC NETS PETROBRAS CONTRACT This was a follow-up Petrobras has awarded TechnipFMC an EPCI contract for the to trials completed Copyright © 2019 Oceaneering International, Inc. All rights reserved. Mero 1 presalt field development in 2,100 m (6,890 ft) of water last September when The Ambient Lifter at Buckie Harbor in the Santos basin offshore Brazil. This covers engineering, it lifted a 5-metric during its recent pre-trial tests. (Courtesy Ecosse IP Ltd.) procurement, construction of all rigid lines, and installation ton load from the As your trusted decommissioning partner, Oceaneering does things differently, creatively, and and pre-commissioning of the infield riser and flowline system seabed. Building on the results, EIP’s engineering team scaled smarter. From providing discrete tools to offering a turn-key, end-to-end decommissioning solution, for interconnecting 13 wells (six producers and seven water up the system by doubling its lifting capacity to 10 metric tons our track record is based on reliable cutting services and complimentary tooling. We can handle alternate gas injectors) to the FPSO. It also includes installation and adding an ROV garage and docking interface. The company large work scopes including vessel services, ROV, tooling, and project management. of rigid pipelines (including corrosion-resistant alloy and steel plans full harbor trials this month. lazy wave risers), flexible risers and flowlines, steel tube umbil- Dorothy Burke, EIP’s managing director, said: “We are de- By working together will we safely and reliably re-shape the future of the oil and gas industry. icals, and other subsea equipment. lighted The Oil & Gas Technology Centre is supporting our next trials and also look forward to working with Oceaneering and Aleron on the next phases through to commercialization.” Connect with what’s next at oceaneering.com

14 WWW.OFFSHORE-MAG.COM | OFFSHORE MARCH 2019

Ocean_OS_1903 1 2/14/19 11:21 AM 1903OFF06-19.indd 14 2/28/19 4:22 PM Connecting What’s Needed with What’s Next™

SOLVE YOUR DECOMMISSIONING CHALLENGES

As your trusted decommissioning partner, Oceaneering does things differently, creatively, and smarter. From providing discrete tools to offering a turn-key, end-to-end decommissioning solution, our track record is based on reliable cutting services and complimentary tooling. We can handle large work scopes including vessel services, ROV, tooling, and project management.

By working together will we safely and reliably re-shape the future of the oil and gas industry.

Connect with what’s next at oceaneering.com

Ocean_OS_1903 1 2/14/19 11:21 AM 1903OFF06-19.indd 15 2/28/19 4:22 PM JESSICA STUMP • VESSELS, RIGS, & SURFACE SYSTEMS HOUSTON

TELFORD OFFSHORE ACQUIRES SEVEN VESSELS The average age of the company’s current 44-vessel fleet has Telford Offshore has acquired a DP-3 pipelay and accommoda- been reduced to less than 10 years. The fleet consists of 30 AHTS tion vessel and six offshore support vessels following a legal vessels, 12 subsea support vessels, and two platform supply Y settlement between Sea Trucks Group (STGL in liquidation) vessels. and West African Ven- tures. The transaction NOBLE BUYS SECOND NEWBUILD JACKUP FROM R brings the company’s PAXOCEAN PREDICTIVE Intelligent Controls DP-3 fleet to five. Noble Corp. plc has exercised an option for the purchase of a The DP-3 vessel, Jas- second newbuild Gusto MSC CJ46 design jackup rig from the con 30, is set to be dry- PaxOcean Group for $83.75 million. docked and upgraded in Like the Noble Johnny Whitstine, which it purchased last A preparation for use September in connection with a Saudi Aramco contract, the worldwide under its new newbuild CJ46 design jackup, to be named the Noble Joe Knight, name, Telford 30. The The Jascon 30, a DP-3 pipelay and was built at the PaxOcean Graha shipyard in Batam, accommodation vessel, will be vessel is expected to be Indonesia. REGENERATIVE N renamed Telford 30. (Courtesy Telford Active Sealing Revolutionary ACD ready for deployment Offshore) The rig is built for operations in moderate drilling environ- later this year. ments and can operate in water depths of up to 375 ft (114 m), provides consistent The six offshore support vessels, which are all anchor han- with well depths of 30,000 ft (9,144 m). The rig features a modern dlers, will be deployed in Nigeria with the company’s partner drilling control system, along with a versatile cantilever skidding seal performance O Afrimarine Charters. They will be prepared to start work on system and two BOPs.

projects during 1Q 2019 as Telford moves to increase its presence The Noble Joe Knight will be relocated to a shipyard in Sin- I Plan efficiently and enhance the safety and and commitments in Nigeria and West Africa. gapore for commissioning and final outfitting ahead of the performance of deepwater MPD with our expected start of operations during 3Q 2019 under a three-year CONSISTENT next generation Active Control Device (ACD). MAERSK SUPPLY SERVICE COMPLETES FLEET primary term contract, plus a one-year option, with Saudi Variable Closing Its revolutionary pressure-sealing system T RENEWAL PROGRAM Aramco. Pressure provides constant wellbore sealing without Kleven has delivered the Maersk Maker, the sixth and final Julie J. Robertson, chairman, president and CEO of Noble bearings or rotating components. As the seal vessel of Maersk Supply Service’s Starfish AHTS newbuild Corp. plc, said: “The CJ46 design is an ideal drilling unit for sleeve wears, pressure is actively applied to series. many applications in the Middle East…” maintain a consistent seal, saving both time The Maersk Maker is a DP-2 deepwater anchor handling tug U and money. Performance-proven technology supply vessel (AHTS) of LIZA FPSO EXPECTED TO SAIL-AWAY THIS SUMMER that mitigates the risk of unplanned events SALT design. Powered by SBM Offshore has issued an update on its FPSO construction while drilling challenging hole sections—so five medium speed en- programs. CONTINUOUS L gines with total output In the Fast4Ward program, the company’s first standard, Real-time Condition you can advance with confidence. Monitoring of more than 23,000 multi-purpose hull is progressing well and according to schedule horsepower, a fuel effi- at the Shanghai Waigaoqiao Shipbuilding and Offshore (SWS) cient and flexible hybrid shipyard in China. Last November, the company contracted the afglobalcorp.com/drilling O propulsion system and SWS shipyard to build the second hull for which progress is in fixed pitch on all side line with expectations. Due to anticipated demand, SBM has thrusters, the vessel is progressed negotiations to start work on its third standard, The Maersk Maker is a DP-2 said to provide good fuel multi-purpose hull. These negotiations are expected to be closed RELIABLE V economy, low emissions, deepwater anchor handling tug supply in 1Q 2019. No Rotating Parts and good station keeping vessel. (Courtesy Maersk Supply Construction of the FPSO Liza Destiny at Keppel Shipyard Service) capabilities (ERN 4 x 99). in Singapore is progressing well, the company said. The last

Also designed for high safe deck operations, the vessel is modules were lifted on board and commissioning activities are E equipped with a multi deck handler system, anchor recovery under way. Sail-away is planned for this summer so that the frame, gypsy handling system and other aids. vessel can be installed offshore Guyana later in the year. The vessel’s arrival completes the company’s fleet renewal In Guyana, work is under way with respect to operations

program, with 10 newbuild vessels delivered and 23 vessels readiness, setting up the shore base and delivering on its local R divested over the last three years. Since March 2017, six M-class content commitments. AHTS vessels of the Starfish series and four I-class subsea The company added that with engineering now nearly com- support vessels of the Stingray series have joined the Maersk pleted, the fabrication of the turret mooring system for the Supply Service fleet. Both vessel series, the company says, have Johan Castberg FPSO is well advanced in Dubai. It remains on been designed to optimize reliability, energy efficiency, comfort, track to meet Equinor’s schedule with delivery in early 2020. and safety. Agile thinking. Engineering change.

16 WWW.OFFSHORE-MAG.COM | OFFSHORE MARCH 2019

AFGlobal_OS_1903 1 2/20/19 1:15 PM 1903OFF06-19.indd 16 2/28/19 4:22 PM Y

PREDICTIVE R Intelligent Controls A

REGENERATIVE N Active Sealing Revolutionary ACD provides consistent seal performance O

I Plan efficiently and enhance the safety and performance of deepwater MPD with our CONSISTENT next generation Active Control Device (ACD). Variable Closing Its revolutionary pressure-sealing system T Pressure provides constant wellbore sealing without bearings or rotating components. As the seal sleeve wears, pressure is actively applied to maintain a consistent seal, saving both time U and money. Performance-proven technology that mitigates the risk of unplanned events while drilling challenging hole sections—so CONTINUOUS L Real-time Condition you can advance with confidence. Monitoring

afglobalcorp.com/drilling O

RELIABLE V No Rotating Parts E R

Agile thinking. Engineering change.

AFGlobal_OS_1903 1 2/20/19 1:15 PM 1903OFF06-19.indd 17 2/28/19 4:22 PM BRUCE BEAUBOUEF • DRILLING & PRODUCTION HOUSTON

STENA FORTH TO DRILL JETHRO-LOBE OFFSHORE the deepwater Egyptian sector of the Mediterranean with the GUYANA Merak well. The partners in the Orinduik block offshore Guyana have con- Off Morocco, Chariot Oil & Gas’ Moh-B well will test a pros- tracted the drillship Stena Forth for their first exploration well. pect that could hold 637 MMboe. After completing its current program offshore West Africa, The Central Tano-1 well offshore Ghana will target up to 2.3 the rig is set to spud the well on the 250-MMbbl Jethro-Lobe Bbbl of oil, while offshore Namibia, Total’s well on the Venus prospect in June, close to and up-dip from numerous discoveries prospect will be the deepest anywhere to date offshore Africa, in the deepwater Stabroek block and in the same proven re- Rystad claimed. source intervals. Venus, also considered to be the largest prospect drilled so According to one of the block partners Eco (Atlantic) Oil and far off Namibia, is in a giant basin floor fan of the Orange Gas, the agreement with contractor Stena also defines a window basin. for a second well after Jethro-Lobe has been drilled. West of Shetland, Hurricane Energy is set to drill a deepwater well on a prospect with a pre-drill estimate of 935 MMboe – the company is said to have indicated a 77% chance of success. The Dunquin South well offshore western Ireland will pursue hydrocarbons in lower Cretaceous carbonate reservoirs in water depths of 1,500 m (4,921 ft). Here the pre-drill estimate is for up to 1.4 Bbbl of oil. In the Gulf of Mexico, Total plans a well on the ultra-deepwater Etzil prospect, which has a 2.7 Bboe pre-drill resource estimate. Offshore French Guiana, the company is set to commit $114 million to drill the Nasua-1 ultra-deepwater well (1 Bboe pre-drill). Finally, Shell will drill the Gato do Mato presalt prospect off Brazil, which the company bid for in the second presalt licensing round in 2017. The partners in the Orinduik block offshore Guyana have contracted “In 2018 we saw that the decline in offshore exploration the drillship Stena Forth for their first exploration well. (Courtesy Stena Drilling) activity came to an end,” Patel said. “The total number of offshore exploration wells last year was Colin Kinley, Eco Atlantic’s COO, said: “While the Jethro-Lobe 325, compared to around 335 in 2017. For 2019 we expect that is a Tertiary target, which we believe is similar to the Exxon around 400 offshore exploration wells will be drilled.” Hammerhead discovery that appears to extend onto Orinduik, we will also drill down to test the Cretaceous section below TRANSOCEAN TO UPGRADE FIVE MORE SEMIS WITH Jethro.” DRILLING AUTOMATION Transocean Ltd. has entered into an agreement with Equinor ANALYST SEES UPTICK IN EXPLORATION DRILLING, to license and install automated drilling control (ADC) systems POSSIBLE LARGER FINDS on four high-specification, harsh-environment rigs currently Various offshore exploration wells planned this year could lead on contract in Norway and a fifth semisubmersible that is ex- to ‘elephant’ finds, according to consultant Rystad Energy. pected to start operations in the Norwegian Sea this summer. “Renewed optimism in exploration activities is anticipated In 2017, the semisub Transocean Enabler was equipped with in 2019, with operators from various segments aiming for mul- the ADC system and, the company said, has delivered tangible tiple high-impact campaigns…in essentially all corners of the improvements in overall drilling efficiency that have led to more world,” said senior analyst Rohit Patel. “These include wells cost-effective wells for Equinor. Further, the system has demon- targeting large prospects, play openers, wells in frontier and strated improvements in well integrity, while enhancing safety emerging basins, and operator communicated high impact and operations assurance. w el l s.” The upgraded floaters will include the Transocean Spitsbergen, Rystad’s new High Impact Wells Report lists the top wildcats Transocean Norge, Transocean Encourage, Transocean Equinox, to watch over the coming year. and Transocean Endurance. Offshore Papua New Guinea, the Mailu-1 well will target a The ADC systems are developed through the combination giant carbonate oil prospect which if successful, could open a of various technologies from MHWirth, NOV, and Sekal AS, new ultra-deep offshore play. which enable, among other things, higher rates of penetration Eni’s Kekra-1 well is Pakistan’s first ultra-deepwater well in while drilling, highly stable bottomhole pressures avoiding over a decade (potentially 1.5 Bbbl). swab/surge effects and early detection of kick/loss events. Dana Gas plans to make its debut as an offshore operator in

18 WWW.OFFSHORE-MAG.COM | OFFSHORE MARCH 2019

1903OFF06-19.indd 18 2/28/19 4:22 PM OFFSHORE WIND ENERGY •

TEKMAR CABLE PROTECTION SYSTEM SELECTED FOR global analysis of the cables and CPS on the project. NORTHWESTER 2 The product will be produced within Tekmar’s manufacturing Tekmar Energy says that the offshore installation contractor facility in northeast England during 2019. Jan De Nul Group has selected the Tekmar Cable Protection System (CPS) TekLink Mechanical Latch for the Northwester ENERGY PRODUCERS JOIN FORCES TO BID FOR 2 offshore wind farm. DUNKIRK OFFSHORE WIND FARM Northwester 2 will be the sixth windfarm in the North Sea Total, Ørsted, a renewable major, and Elicio, a renewable energy off the Belgian coast, consisting of 23 turbines and will provide producer preselected by the French Energy Regulatory Com- a total of 219 MW from its location off the coast of Zeebrugge, mission, have created an industrial consortium to submit a in water depth of approximately 40 m (131 ft). The project is joint bid for the Dunkirk offshore wind farm project for a power set for completion in 2020. capacity of up to 600 MW. Russell Edmondson, Managing Director of Tekmar Energy Philippe Sauquet, President Gas, Renewables and Power at said: “We are delighted for Tekmar to be selected as the cable Total said: “Total’s participation in this offshore wind bid is in protection system supplier for Northwester 2. This continues line with our strategy to develop low-carbon electricity business Tekmar’s trusted relationship with Jan De Nul Group and furthers in Europe. Our recognized offshore oil and gas know-how com- our position as the world market leader in offshore wind cable bined with Ørsted market-leading expertise across the offshore protection systems; marking Tekmar’s 66th project within the wind energy value chain, as well as that of Elicio, an experienced industry, taking the total number of systems over 6,700 and developer qualified from the beginning of the bid, provide a 22GW of protected subsea electrical infrastructure solid foundation for success of a safe and competitive worldwide.” project.” Martin Neubert, CEO of Ørsted Offshore, said: “Offshore wind can contribute significantly to France’s renewable energy targets. As the world-leading offshore wind developer, we bring an unparalleled track-record in developing, constructing and operating offshore wind farms to the consortium, and the combined competencies of Ørsted, Total, and Elicio are ideal to help France unleash its significant potential for developing clean power from offshore wind.” Emile Dumont, President of Elicio France, said: “Wind energy has significant growth potential in France and is at the heart of Elicio’s strategy to contribute towards a cleaner and cost-effective energy powered world. Further to Elicio’s successful preselection for the French round 3 competitive dialogue and by joining our unique expertise and experience, we are committed, with our partners Total and Ørsted, to making this tender a milestone in the French offshore wind sector.” Tekmar Cable Protection System on the back of a Jan De Nul Group vessel installing an offshore wind project. SEAOWLS, ULSTEIN GO THEIR OWN WAYS IN HEAVY The award also continues the success of Tekmar in the region, LIFT JACKUP VESSEL MARKET after being selected for several adjacent windfarms including Rotterdam-based companies SeaOwls and Ulstein Design & Belwind, Belwind demonstration, Thornton Bank 2 and 3 and Solutions have decided to each go their own separate ways in Borselle 1, 2, 3, and 4. the offshore wind industry. The patent rights of the SOUL Stan Logghe, Senior Project Manager at Jan De Nul Group concept were developed under the cooperation of both com- said: “Cable protection systems are vital for protecting the panies and will continue to be held by both SeaOwls and Ulstein. electrical infrastructure of offshore wind farm projects. We have Each company will pursue its own business opportunities based worked with Tekmar for many years, on projects including on the shared patent. Burbo Bank and Race Bank, and Northwester 2 builds on our The heavy lift jackup vessel design concept is said to be the strong and trusted relationship.” safest and most efficient solution to transport and install the As part of the project, Tekmar will supply its latest TekLink world’s largest and powerful offshore wind turbines in the Generation 8 cable protection system for all inter array and coming decades. SeaOwls and Ulstein say they are committed export cables. to assist their clients to build the most suitable jackup vessel AgileTek Engineering, a Tekmar Group company, also sup- to enable the industry to take the next step to a sustainable ported the project using its proprietary AEL cloud system, world. providing verification of the cable protection system design via

MARCH 2019 OFFSHORE | WWW.OFFSHORE-MAG.COM 19

1903OFF06-19.indd 19 2/28/19 4:22 PM • SEISMIC VESSEL MARKET UPDATE Challenges remain for seismic survey vessel market Ranks of active contractors have declined significantly

BRUCE BEAUBOUEF, MANAGING EDITOR

WHILE MUCH of the offshore industry is slowly rebounding from the downturn, the Shearwater GeoServices reports seismic vessel survey market continues to that its multi-purpose vessels WG Tasman and WG Cook (pictured) be challenging for those contractors that will be deployed for work in still remain active. the North Sea during the 2019 And that list has become much smaller summer season. in the past few years. Companies that have exited the market include CGG, Fugro, and WesternGeco. Companies that have filed for bankruptcy include Dolphin Geophysi- cal, Global Geophysical Services, Geokinet- ics, and REFLECT Geophysical. During the past few years, much of the existing seismic survey fleet has changed hands. One such deal was concluded last November, when Shearwater GeoServices completed its acquisition of the marine seismic acquisition assets and operations of WesternGeco, the geophysical services product line of Schlumberger. With the completion of the deal, Shearwater officials observed that the transaction makes Shearwater a global provider of marine geophysical services, which owns and operates a fleet of 14 fully equipped seismic vessels offering a full range of acquisition services including 3D, 4D and ocean bottom seismic. To be sure, there are a number of companies that remain active in the market. They include SeaBird Exploration, Polar- cus, PGS, EMGS, and others. SeaBird recently announced the extension of two existing contracts. The contract for the Voyager Explorer, which is working on an ocean bottom node survey in the Far East, was extended by approximately 90 days until March 2019, with an option for the charterers to extend by another 30 days. The Osprey Explorer is also working on an ocean bottom node survey in the Ameri- cas region. This contract has been extended from initially 60 days to currently approximately 180 days. Following the completion of this contract expected in early March

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PGS’s Ramform Tethys, first launched March 2016, has been working offshore Brazil.

PGS reports that Phase 4 of the multi-sensor Sabah multi-client 3D is under way with the Ramform Hyperion. PGS says that Sabah is one of the largest multi-client projects worldwide and the first ever in Malaysia. The company says that it will acquire up to 10 000 sq km of GeoStreamer data, adding to the existing 37,000 sq km multi-phased Sabah MC3D, which PGS says is already one of the world’s largest multi-client acquisition projects. EMGS reports that its Atlantic Guardian vessel has completed an $8-million seismic survey offshore South America. The company says it expects to operate two acquisition vessels globally in 2019 and plans to continue investing in its multi-client library The Polarcus Amani is currently acquiring in select areas. an ultra-wide 3D marine seismic project offshore Myanmar. However, its capital investment plans are limited to maintenance of existing equipment. EMGS says the market outlook for oil 2019, SeaBird says that the Osprey will immediately commence on a previously announced services remains challenging and uncer- ocean bottom node survey in the same region with expected completion in mid-April 2019. tain, although there has been an increase Polarcus says that it is currently acquiring an ultra-wide 3D marine seismic project in commercial activity. It has received offshore Myanmar. The Polarcus Amani is towing an in-sea configuration that measures increasing numbers of enquiries concern- 1.8 km wide across the front ends. With each of the 10 streamers separated by 200 m, the ing proprietary acquisitions outside of its total area covered by the spread is 17.6 sq km. Polarcus says that this is the largest in-sea stronghold, Norway. configuration ever towed by a single seismic vessel, as well as the largest man-made mov- And, that cautionary note is also being ing object on earth. sounded by consultancies and analyst firms

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as well. While more front-end engineering and design work is Spectrum, in cooperation with BGP, has started a 20,000-km being awarded, new orders on larger, greenfield projects that will (12,427-mi) 2D survey in the Colorado and Salado basin offshore be sanctioned in 2019 will not help build contract backlogs until Argentina. This new program ties with the company’s existing 2021. While the (now smaller) seismic survey vessel market may 38,000-km (23,612-mi) survey that was acquired in 2017 for the be poised for a recovery, there are still a number of survey vessels ongoing first offshore licensing round. still stacked at quayside. These vessels will likely not be hired for The BGP Pioneer is conducting the survey. Data is being acquired at least another year, analysts predict – or not until oil companies with a 12-km (7.5-mi) streamer with continuous recording to image begin maturing remote acreage. deep reflection and high fold data. This will support full interpre- The companies that participated in Offshore’s 2019 seismic ves- tation from Moho to water bottom. The data will be processed sel survey, and their latest data, can be seen below. with PSTM, PSDM, and Broadband products. First deliveries are expected in 2Q 2019. MULTI-CLIENT SURVEYS Shearwater GeoServices says it has been awarded a major explo- Meanwhile, the industry continues to make use of data obtained ration survey in Brazil by TGS. The project will be executed by the from multi-client surveys to plan new exploration and drilling Amazon Warrior using proprietary Q technology starting in Q1 2019. campaigns. The companies report that the Amazon Warrior will be employing

OFFSHORE WORLDWIDE SEISMIC VESSEL SURVEY *only includes companies that responded to survey Onboard processing Acquisition capability Technical capability Seismic

2D 3D 4C/4D Vessel name Vessel or rigged Year converted length (meters) Total beam (meters) Total configuration Streamer x # (# streamers channels) Availability Vessel Region Primary array Source as rigged configuration x capacity in (# arrays cu in) towable Maximum x (# cables footprint length (m) x width (m)) Shallow zone transition Deepwater High density Ocean bottom cable depth Variable data Nav QC data data Full recording primary Final media (type or cartridge #) transmission Satellite (company shore to used and transmission speed (baud))

Dalmorneftegeophysica (DMNG), 426, Mira Ave., Yuzhno—Sakhalinsk, 693004, Russia Akademik DigiStreamer 1 SE Asia / 1 array 4 string 2007 81.5 14.8 Contact 1 x 12,000 X — — X X — — — X X X 3592 VSAT Fersman x 960 Worldwide 6,080 Max 1 array 4 DigiStreamer 1 SE Asia / strings 3,400 Zephyr—I 2007 81.8 14.8 Contact 1 x 12,000 X — — X X — — — X X X 3592 VSAT x 960 Worldwide higher on request Fairfield Industries,1111 Gillingham, Sugar Land, Texas 77478, USA NA — OBN Rem Saltire 2019 100 24 Node Handling DP2 Gulf of Mexico NA NA X X X X X X X X X — 3592 — Vessel NA — OBN Normand 2018 95 21 Node Handling DP2 Gulf of Arabia NA NA X X X X X X X X X X — 3592 — Tonjer Vessel NA — OBN Mac Pegasus 2018 87 18 Node Handling DP2 Gulf of Arabia NA NA X X X X X X X X X X — 3592 — Vessel PGS, Lilleakerveien 4C, N—0216 Oslo, Norway Ramform Titan 2013 104.2 70 20 x 1296 Yes Worldwide 2 x 4,130 14.4 sqkm — X X — X X — X X X X 3592 512K Ramform Atlas 2014 104.2 70 20 x 1296 Yes Worldwide 2 x 4,130 14.4 sqkm — X X — X X — X X X X 3592 512K Ramform 2016 104.2 70 20 x 1296 Yes Worldwide 2 x 4,130 14.4 sqkm — X X — X X — X X X X 3592 512K Tethys Ramform 2017 104.2 70 20 x 1296 Yes Worldwide 2 x 4,130 14.4 sqkm — X X — X X — X X X X 3592 512K Hyperion Ramform 2008 102.2 40 18 x 1296 Yes Worldwide 2 x 4,130 14.4 sqkm — X X — X X — X X X X 3592 512K Sovereign Ramform 1999 86.2 39.6 16 x 1296 Yes Worldwide 2 x 4,130 12 sq km — X X — X X — X X X X 3592 512K Vanguard PGS Apollo 2010 106.8 19.2 10 x 1296 Yes Worldwide 2 x 4,135 12 sqkm — X X — X X — X X X X 3592 512K Sanco Swift 2014 96 23 12 x 1296 Yes Worldwide 2 x 4,135 14.4 sqkm — — — — X x — X X X X 3592 512K Atlantic 1994 91.5 18 1 x 1608 Yes Worldwide 2 x 4,130 3.6 sq km X — — — X — — X X X X 3592 512K Explorer

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its single-sensor Qmarine technology, which they say is suited to chain transform zone exert a major influence on the tectonic regime. environmental conditions offshore Brazil. The 11,200 km2 survey The northern shoulder of the Niger Delta, the company adds, is expected to last approximately 8 months including transits. contains almost all the regional structural domains associated with Still elsewhere, PGS reports that its UK imaging center aims shale tectonics in the region, barring the deformed and thrusted to deliver first results this spring from a re-processed multi-client shale diapiric domain. 3D (MC3D) pre-stack depth migration (PSDM) dataset offshore Between the 1990s and last March, many fields were discovered Nigeria. This will cover the newly relinquished blocks OPL321 to the south and east, including the giant Bosi (1996), Erha (1999), and OPL323, also integrating data acquired in 2004 over blocks and Oyo North (2018). OPL314 and OPL315. The most recent exploration identified at least eight prospects The MC3D OPL 314/315/321/323 spans the area between the within this petroleum system with potentially billions of recov- Benin Embayment and the Benue Trough, and should assist inte- erable barrels of oil over blocks covered by the present depth-re- grated exploration of the northern and eastern Gulf of Guinea. processed survey. PGS says the area has numerous similarities to the joint devel- Numerous deepwater channel complexes and shale-cored folds opment area and offshore São Tome & Principe, southeast of the of multi-kilometric scale extend throughout the survey area form- Niger Delta. Here large dextral regional transform faults such as the ing the cornerstones of the Post-Akata exploration. •

OFFSHORE WORLDWIDE SEISMIC VESSEL SURVEY *only includes companies that responded to survey Onboard processing Acquisition capability Technical capability Seismic

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Elements coming together in Oscilay static closing point. (All images courtesy Aker Solutions)

Oscilay process speeds production, cuts cost of long-length umbilicals First deployment offshore China in 2020

JEREMY BECKMAN, EDITOR, EUROPE

CNOOC HAS SANCTIONED the first commercial run of a new benefit is that it eliminates the need for splicing of cables due to umbilical manufacturing method for a subsea tieback project in manufacturing weight and volume constraints. This is said to the South China Sea. Aker Solutions’ Oscilay machine will pro- enable faster production of large diameter heavy power umbili- duce the static sections of the Liuhua 16-2 power umbilicals, part cals, with positive consequences for offshore project schedules. of a package of more than 115 km (71.5 mi) of dynamic and static An Aker Solutions team in Malaysia is leading engineering for the power umbilicals the company is supplying that will connect Liuhua project, with the team in Mobile, Alabama, responsible wells at the deepwater Liuhua 16-2, 20-2 and 21-2 gas-conden- for all production. Final delivery is scheduled for 2020. sate fields to a new FPSO. Aker Solutions is currently construct- Power umbilicals are a critical component of the so-called ing a new building to house the Oscilay closing line. subsea factory, distributing power from platforms to seabed The new process has been designed to address the challenges pumping and production systems in locations often remote from presented by extreme tension loads on umbilicals during instal- infrastructure. As a paper delivered by Aker Solutions at OTC lation, said Greg Ross, the company’s VP Subsea Sales in Asia 2017* pointed out, the design challenges are greater than those Pacific at the time of the contract award last summer. Its main of electrohydraulic umbilicals, typically related to heat transfer,

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corrosion, induced current and splicing. Power umbilicals require much larger-diameter power cables restricting the length and volume that will fit on pay-off reels, which means that each time a reel has to be changed out, splices must be performed. These can often take a week to complete. Until now, the industry has mainly used vertical or horizontal planetary bundling machines for umbilical manufac- ture. With the vertical system the elements are placed on a turntable and are twisted together, as they are drawn upwards, to form a cable. For each ‘closing,’ a central element or bundle is pulled through the center of the turntable, allowing new elements to be added. Horizontal cabling machines employ large wheels instead of turntables to carry the machine reels, but otherwise the assembly process is similar to the vertical approach.

SZ STRANDING Oscilay is an adaptation of SZ stranding as an alternative closing method. SZ stranding, which has long been applied for bundling smaller cables, involves rotating the tooling that bundles the various elements together. Rotating the tooling back and forth equally for each pattern prevents twist building up between the tooling, element pay-off reels and the take-up reel. The main benefits are that the machine reels are stationary (which is said to make the machinery less costly than planetary systems with a similar capacity), and the fact that the pay-off reels can be sized TOP: Large payoff reels going toward Oscilay closing point. without volume or weight limitations. BELOW: Oscilay prototype umbilical during bend under tension tests. However, power umbilicals are subject to high tensile loads, and applying a high tension to a standard SZ cable would elements are given 100% back twist to limit the torque generated by the elements. But cause it to untwist or straighten out. This the large planetary bundling machines that are needed to rotate the individual element action is induced mainly by the torque of reels also have weight limitations of roughly 25-35 tons for each position in the plan- the internal SZ stranded elements. Aker etary. The process of closing can therefore be run continuously only for a length cor- Solutions decided to investigate whether responding to the same weight or volume range for a single element. Mindful of this it might be possible to modify SZ strand- limitation and the associated need for more welding and splicing, the team sought to ing for long umbilicals. The company’s develop and qualify an alternative bundling process that would eliminate the weight typical, planetary umbilicals are bundled and volume constraints. In addition, there are 21 positions in the planetary bundling in one continuous direction with a low machine for elements, whereas the Oscilay machine contains theoretically an unlimited lay angle. The elements are bundled into number of element positions. That eliminates the need for multiple passes through the separate holes within the structure, each closing machine for umbilicals with more than 21 elements. larger than the element they support in According to Ruth Pleasant, Senior Engineer and Product Specialist for Oscilay: order to facilitate spooling of the umbil- “The initial ideas for Oscilay started in 2006 when Aker Solutions realized that there ical. During bundling, the internal helix was an increasing market for power umbilicals with large power cores. This was due to

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the growing need for subsea pumping and also the future market for offshore floating wind power. We realized that our bundling machines in Moss, Norway and Mobile, Alabama were not suitable for the high weight and big volumes of the larger power cores being bundled into the umbilicals. “As shorter-length power cores were needed to suit the weight and volume capacity of a standard planetary machine, our team came up with a new idea which eliminated the weight and volume limitations. This would involve manufacturing a helical bundled umbilical but in an ever-changing direction of the bundling operation, dispensing with the need for planetary action. All elements to be bundled could stay on the ground. The idea was also based on the principle that all axial force should be taken by the internal laid members, even if they were in an alternating helix configuration. We could couple the outer jacket and the internal PVC elements in rotation to balance for the torque generated by the internal elements. “Aker Solutions holds several patents on this idea, the first being filed in 2007. To prove the concept, the first prototype, which was 70 m [229 ft] long, was assembled by hand in 2007 at the Moss plant. During 2007-2009 several more prototypes were made and compared with analysis to further prove and refine the concept. It became clear that the USAP software, developed by Marintek Norway and applied for the stress analysis, needed further development to properly handle the behavior of the alternating helix configuration. The design and engineering was a team effort between our engineering groups in Fornebu (near Oslo), Moss, and Mobile. They worked together very closely throughout the design, manufacturing and testing of the prototype umbilicals, with the majority of the prototype tests being conducted in Mobile. The Alternating Helix Phase 2 project and the large power umbilical prototype project were executed primarily in Mobile.” The main driver for the development has been the pressing need to reduce the time taken to make long-length power umbilicals. “Medium-voltage cable splicing takes several days and is quite complex,” Pleasant explained. “This has to be strong, water resistant, electrically sound, and, critically, it needs to have approx- Aerial view of Aker Solutions’ imately the same diameter as the original cable. Considering that Mobile, Alabama facility with completed umbilicals medium-voltage cables usually come in triads, the process could on carousels made with easily last four or five days. If you have to do this every few kilo- traditional horizontal meters, making a 100-km [62-mi] power cable might take most planetary bundling method of the year. The opportunity cost of manufacturing something and payoff reels feeding into the building for the Oscilay so slowly is prohibitive. closing point. “In order to produce power umbilicals at a pace that would support the market’s needs, Aker Solutions developed what was first known as the Alternating Helix process, later renamed Oscilay. As a nice set of side-effects, the Oscilay process reduces All elements are run into a static closing point and then twisted the material handling and requires much lighter machinery.” back and forth. As the umbilical exits the twist head it is taped to maintain the global configuration. The resultant product is then LAY PATTERN extruded to lock in the umbilical pattern. With this process, there The process follows conventional mono-directional helix strand- are none of the weight and volume constraints of conventional ing principles except for its lay pattern. After a couple of pitch planetary bundling machines, the company claims. lengths, the direction of closing changes, and the constant switch Among the main beneficiaries are long-length power umbili- of lay-direction means there is no need for the individual ele- cals with larger power cores that traditionally reach weight/vol- ments’ pay-off reels to be placed in a planetary or on a turn table. ume constraints after only 3-4 km (1.8-2.5 mi) of construction.

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This forces the bundling process to be halted to allow for re-load- the same long lay length and PVC design as the company’s plan- ing and splicing of power cores. With the SZ stranding principle, etary design and would need to withstand the same installation however, all splicing can be conducted prior to initiating clos- and operation loads. The next steps would be to determine what ing, and with more pay-off reels being placed on the ground, the was new about the technology and what was field proven, and umbilical can always be closed in a single operation. to assess the key areas of focus during the qualification program Aker Solutions decided to evaluate the proposed new process using failure modes effects analysis (FMEA). To support the via a series of prototype tests in accordance with recommended development, the company invited offshore operators, instal- DNV practice on qualification of new technology (RP-203, July lation contractors, and engineering groups to suggest potential 2010). The umbilicals used for the qualification would employ failure modes for the umbilical manufacturing, installation and

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operational phases, many of which would be addressed during SMF fiber optic cables, fiber optic sensors, steel rods, and car- the testing phase. bon fiber rods. A total of 1,000 m (3,281 ft) was manufactured. “In In addition, it resolved to conduct standard tests in accordance order to better understand the technology’s capabilities, many with API 17E:2010 in order to compare the SZ stranded umbilical hand samples were also made prior to producing these umbili- with a standard planetary umbilical. The aim was to draw up an cals with the Oscilay machine,” Hickman added. envelope for making steel tube and power umbilicals without the Results from the qualification program suggested that Oscilay need for extensive, project-specific tests. For the critical tensile stranding would perform well, even in deepwater, and that the testing the company opted for a steel tube umbilical cross-sec- technique could withstand the same tensile, compression and tion that would have required two passes through the cabling internal pressure loads as a planetary umbilical. “The samples machine, thereby ensuring smaller umbilicals would easily com- tested exhibited improved fatigue capacity and high torsional sta- ply with the highest-risk failure modes identified by the FMEA. bility,” Hickman said, “but the same applies to all Aker Solutions Three different prototypes were manufactured with much umbilicals. Since each element is placed in its own conduit, ele- of the testing completed prior to spring 2017. The main consid- ment friction forces are lower than with our competitors’ prod- erations that influenced the testing program included unpre- ucts, and the reduced friction stress lowers the fatigue damage dictable behavior during spooling and reeling due to the new on large power cores. lay pattern; load shar- “ Th e ov eral l ing among elements mechanical properties toward the center of for an Oscilay umbili- the cross-sections vs cal, such as tensile those elements toward capacities and mini- the outer periphery; mum bending radii, filling of the grooves in are the same as for the PVC profiles and planetary umbilicals the subsequent effect that the company has on the umbilical when delivered since 1994. subjected to high ten- The main benefit to our sile loads; whether the clients is that this tech- machine would have nology requires fewer the capacity to twist splices, which means an umbilical incorpo- reduced risk. Also, we rating 15-ksi steel tubes; can deliver faster since and whether the pro- splicing is very time cess would suit umbil- and labor-intensive. ical-grade flying leads. “We are now pur- The trials conducted chasing larger reels for included handling, projects to make full spooling, reeling, ten- Oscilay prototype umbilical taped and entering tensioner. use of the Oscilay tech- sile testing, bending nology. This will allow stiffness testing, bend under tension testing, crush testing, and us to make the full lengths with no splices. Case studies, tenders, flex fatigue testing. and active projects show a reduction in cost of over 5% while also According to David Hickman, Product Manager, Umbilicals eliminating the cable splices.” at Aker Solutions, “one of the prototypes was a 171-mm OD steel First Oscilay production is due to start in 3Q 2019, although tube umbilical (STU) sample containing twelve ¾-in. 15-ksi lines, the new building and equipment will be ready by mid-year. “This four ½-in. 15-ksi lines, three 10-sq mm [0.01-sq in.] quads and manufacturing line will greatly increase the capacity of the Mobile three 16 SMF fiber optic cables. A total of 600 m [1,968 ft] was facility,” Hickman said. “Since the Oscilay machine is small, easily produced. Another was an umbilical-grade flying lead (UFL) moved and very simple, a basic building design is required. The sample containing ten ½-in. 10-ksi lines. In total 250 m [820 ft] first umbilical to be produced using the new process will con- was produced. Both the STU sample and the UFL were tested tain medium-voltage cables and will be an Aker Solutions stan- according to ISO-standard requirements. These two projects dard PVC design. There are no planned splices during closing were designed to be very close to previously executed plane- since the project is taking full advantage of Oscilay’s benefits.” • tary umbilical projects so that the results of testing and analysis could be compared.” REFERENCE The third prototype was a complex power umbilical manu- *Arild Figenschou, David Hickman, and Leif Høie, Aker Solu- factured and tested to suit the requirements of a major oil com- tions, ‘New Umbilical Manufacturing Method Eliminates Weight pany. It included three 630-sq mm (0.97-sq in.) 36kV cables, 16 Limitation,’ Offshore Technology Conference 2017, Houston.

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DGH officials at the presentation in London. (Courtesy Spectrum Geo) Gabon offers wide-ranging blocks, improved terms in latest license round New data highlights pre/post-salt oil potential

JEREMY BECKMAN, EDITOR, EUROPE

GABON HAS OPENED its 12th Offshore Licensing Round, tabling Edgard Mbina-Kombila, Deputy General Manager at the DGH, 35 blocks for exploration and production in relatively shallow to said Gabon’s government had validated a new Hydrocarbons Code ultra-deepwater. All were covered by recent 3D and 2D seismic sur- and that ratification was now in progress: “Gabon has over 60 years veys acquired by four geophysical contractors and processed using history of oil production. Now it’s declining, but we think we can modern techniques. These have delivered a clearer picture of the improve the production profile because there are still non-explored long-suspected potential across the country’s multiple sub-salt and areas, especially over the deep offshore.” New discoveries should be post-salt plays. relatively straightforward to develop, he suggested, with a long-es- Officials from Gabon’s Direction Génerale des Hydrocarbures tablished network of refineries and terminals in place, along with an (DGH) and representatives of the four contractors outlined the new extensive offshore and onshore pipeline system, “so there is no need fiscal terms and exploration opportunities at a presentation in Lon- for companies to put in new infrastructure.” don earlier this year organized by Spectrum. This was one of eight The 2D and 3D datasets acquired by CGG, ION Geophysical, PGS, roadshows to promote the round following its initial announce- and Spectrum under partnership arrangements with the DGH are ment in Cape Town last year. Others will be staged over the com- all available under the new round. The more data companies license ing months at exhibitions and conferences in Beijing, Equatorial ahead of submitting a bid the stronger their work program will be Guinea, Moscow, Calgary, and Brazil. Following requests from the rated, Mbina-Kombila said, with consequent reductions in future industry, the ministry has extended the deadline for license appli- seismic commitments if the bid is successful. cations to Sept. 30, 2019. Herve Bertrand N’nang Engue, Senior Economist at the DGH,

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oil successes last year with the Ivela-1 and Boudji-1 wells. According to a report drawn up by Spec- trum for the ministry for the 12th Round, exploration to date off the north of Gabon has focused on shallow oil post-salt plays in shallow water. The resulting oil discoveries prove the presence of a post-salt hydrocarbon system. In the presalt, there have been a few nearshore gas discoveries but the presalt oil plays have been ignored due in part to imaging restrictions. That situation has changed with advances in imaging and drilling technologies: recent assessments suggest that the deeper presalt synrift close to the shore contains structural plays with quality reservoirs above oil-prone source kitch- ens. And farther to the west the post-salt is so thick the likelihood is that source rocks here will also be oil-generative. Offshore central Gabon, the new license blocks offered are over the outer part of the Ogooue Delta, where water depths were beyond the capabilities of earlier exploration. There appear to be various undrilled structures in the post-salt close to the oil-prolific shallow-water area. New technologies are allowing stratigraphic targets to be imaged over potential sandstone channel, slope and fan plays over underlying salt diapirs. And analysis of post-salt carbonates indicates that the syn-rift is potentially generating billions of barrels of oil, or where it is really thick, gas-condensate, said Spectrum’s Neil Hodgson. Sub-salt plays in the Ogooue Delta have been virtually unexplored. Off southern Gabon, in addition to the Blocks on offer under the 12th licensing round. (Courtesy DGH) proven Gamba sandstone post-rift, presalt plays, modern imaging is for the first time said the new Hydrocarbons Code was based on input from the Gabonese Tax and Customs revealing large, syn-rift anticlines, and the and Environment departments, the country’s upstream and downstream unions, OPEC, the few wells drilled to test this play have been University of Houston, and the African producers’ association APPA. The code is adapted successful. to take into account oil price fluctuations, with flexibility applied to different plays and field sizes. Other positive changes include the removal of corporate income tax, a lower royalty DATA REVIEWS rate on deep/ultra-deepwater production, and higher cost recovery rates of up to 70% for CGG’s focus has been on Gabon’s South conventional oil, and in deep/ultra-deepwater, 80% for oil and 90% for gas. As for license basin. Working with the Ministère du Pétrole, durations, the initial exploration phase has been extended from six to eight years with the Gaz et des Hydrocarbures, the company oil production phase extended from 20 to a maximum of 30 years, 35 years in the case of gas. acquired over 25,000 sq km (9,652 sq mi) of 3D seismic over an area that includes some EMERGING PLAYS of the 12th Round blocks, using its Broad- All of Gabon’s current offshore production comes from relatively near-shore fields, but there Seis broadband technique, full-waveform has been patchy exploration in recent years of the lesser known presalt plays. This has deliv- inversion and tomographic velocity model- ered deepwater successes such as Total’s Diaman-1B gas-condensate discovery in the Diaba ing to image prospective structures at base block in 2013 and Shell’s Leopard (gas) the following year in the BCD license, 145 km (90 salt level. The survey area is also close to mi) offshore and in 2,110 m (6,922 ft) water depth. Two other consortia achieved deepwater and downdip of pre-Aptian salt discoveries

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during the opening of the South Atlantic. ION claims the program has helped resolve issues related to hydrocarbon expulsion and tim- ing and the thickness of Cretaceous units critical to the development of new hydrocarbon concepts. PGS’ Gabon MegaSurvey, another initiative developed with the DGH over the past 10 years, provides over 35,000 sq km (13,513 sq mi) of merged 3D/2D data and regional interpretation over mature and frontier offshore areas, with key horizons calibrated to released well data allowing users to focus on detailed prospect-level interpretation. Spectrum’s most recent efforts offshore Gabon have involved reprocessing in 2016 of a 2D data-set acquired in 2009, followed in 2017 by acquisition of 11,000 sq km (4,247 sq mi) of 3D data over the south (including the currently offered blocks) and subsequently 5,500 sq km (2,123 sq mi) of 3D seismic over the north. The company has finished processing the southern data and expected to finish work Area covered by CGG’s latest Gabon South basin deepwater 2D on the north this month. In addition, it has been cooperating with multi-client survey. (Courtesy CGG) the DGH on reprocessing existing 3D data using modern broadband techniques, said Neil Hodgson. He pointed out that although around such as Ruche and Tortue in the Dussafu block (now under devel- 18 exploratory wells had been drilled in the south on the Dentale opment by BW Offshore) and Diaman, and both Ivela and Boudji Gamba play, only one had found oil. The poor returns appear to be were identified based on this data-set, CGG claims. down to problems with seismic definition clarity: Spectrum has Over 2,500 sq km (965 sq mi) were overshot by perpendicular applied de-ghosting during processing which will hopefully improve 14-km (8.7-mi) long-offset data in order to provide dual-azimuth cov- imaging in this region. • erage, with over 3,800 sq km (1,467 sq mi) acquired applying similar offsets for improved imaging of deeper diving waves. According to the company, the main prospective targets are in deep sub-salt Bar- remian to Aptian sandstones; supra-salt Albian Madiela carbonate turtlebacks; and Cretaceous-Tertiary turbidite sands that have proven to be fertile hunting ground to the south offshore Congo and Angola. Results from the BroadSeis data-set are also incorporated in volume 2 of the CCG/Robertson JumpStart integrated geological study of the South basin. More recently CGG has been acquiring 9,800 km (6,089 mi) of long-offset, broadband 2D data to help define the full extent of existing and newly identified plays in the basin and to assist understanding of the thickness variations in the sediment overburden for source rock and maturity analysis. Broadband processing should improve characterization of the turbidite systems that represent potential “I can think of no one better to translate the complexities of natural gas liquids into a more easily understandable subject.” exploration targets, while the low frequencies should provide sufficient penetration to enhance understanding of the nature of the — Frank H. Richardson, President and CEO, Shell Oil Company, Retired deep crust, the company says. Natural Gas Liquids: A Nontechnical Guide ION, working with the ministry and the DGH, has acquired five 2D is a comprehensive overview of NGLs from surveys over the past few years across Gabon’s entire offshore area, production in the oil patch to consumption in with all the data re-processed, re-imaged and integrated last year the fuels and petrochemicals industries. into the new 2D BasinSPAN data-set. This covers 4,760 km (2,958 Learn what is behind natural gas liquids: mi) off northern Gabon and 6,000 km (3,728 mi) off the south of the • How they are produced country. ION’s Ken McDermott, speaking at the London event, said • How they are transported the new seismic lines over the north show good reflectivity from the • How they are consumed in the fuels salt down to the base of the crust, revealing what appear to be sed- and petrochemicals industry iments curling around salt diapirs. • Prof les of successful NGL companies The SPAN data is said to support development of a full crustal deformation model for the offshore area and provides input to assist ORDER YOUR COPY TODAY AT source rock maturation modeling. Line orientations have been WWW.PENNWELLBOOKS.COM 226 Pages/Hardcover/2014 designed to improve understanding of the initial and subsequent OR CALL 800-752-9764 break-up and transform margin phases that impacted the area

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The heavy-lift vessel Saipem 7000 removing the Miller platform in the UK central North Sea. (Image courtesy BP)

Decommissioning market advancing offshore the UK Association details achievements, opportunities

JOE LEASK, OIL & GAS UK

‘DECOMMISSIONING IS COMING OF AGE’ is a phrase heard fresh investment into the basin. In 2018, final investment deci- in the UK oil and gas industry. Now it is steadily occurring along- sions for 13 new projects were approved attracting £3.3 billion side exploration and production on the UK continental shelf ($4.2 billion) of capital investment with the potential to pro- (UKCS). It is a phrase that aptly describes the sector’s exper- duce 400 MMboe over time, adding to the taxes the UK Trea- tise, accumulated over 30 years of decommissioning offshore sury receives from the sector. structures in the North Sea basin. Ensuring that knowledge is These changes push cessation of production dates and shared is crucial to developing the highly skilled teams needed decommissioning projects into the future. They are helping to to deliver projects cost-effectively. stabilize the market, with decommissioning expenditure pre- When Oil & Gas UK launched its 2018 Decommissioning dicted to even out at about £1.5 billion ($1.9 billion) per year. Insight report in November press headlines like ‘Industry effi- In 2018, decommissioning represented only 8% of the oil and ciency drive cuts UK bill’ highlighted how the competitive capa- gas industry’s overall expenditure on the UKCS. Current trends bilities had improved project delivery. In contrast to reports suggest this decommissioning spend will grow slightly in the published since 2010, this Decommissioning Insight revealed near term, possibly rising to 10%. However, market conditions for the first time a 20% reduction in forecast expenditure over including oil prices and expenditure in areas including explo- the next 10 years in comparison to the 2017 Insight report. ration, well appraisal, and operations will influence how things Transformational changes are taking place on the UKCS. might unfold in the future. Through relentlessly focusing on improving efficiency through- Changing UKCS dynamics offer an invaluable window of out the oil and gas lifecycle, the industry is extending the eco- opportunity. With decommissioning scheduled to occur over nomic viability and productive life of offshore assets, attracting a longer timeline, the country can build on existing specialist

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skills and expertise. While decommissioning is occurring in in the development of tools like the Work Breakdown Struc- other oil and gas provinces around the world, a significant ture (WBS). Giving industry a standard approach to modeling number of UKCS projects are substantial in scale and techni- decommissioning projects, this encompasses all elements of a cally complex. Current market stability promises to deliver a typical decommissioning project. Different expertise is required steady flow of diverse work for the supply chain and a range of within each WBS phase: from engineering practitioners at the stimulating career prospects for people entering the industry. front end to operational expertise as the installation is made The association’s Decommissioning Insight, which encom- safe, to lifting scopes, subsea scopes and finally re-use, recy- passed wider North Sea activity in Norway, Denmark and the cling and disposal. Netherlands, outlined the scale of this opportunity. It confirms Details of the WBS are included in Oil & Gas UK’s Decom- the UK will be the largest market for decommissioning over the missioning Cost Estimate Guidelines. The WBS establishes a next decade providing it with the opportunity to build a regional common language for all those involved in decommissioning; and indeed global capability. Industry analysts like Wood Mack- providing the supply chain with clarity about where they fit enzie, taking a global perspective, observed a similar trend, into the spectrum, outlining good practice in contract execu- anticipating the UK will be where the highest level of decom- tion to operators and defining to the regulators the cost pro- missioning expenditure will take place over the same period. visions per phase. The country’s experienced supply chain has a clear opportu- The WBS includes aspects such as initial field econom- nity to develop world-class decommissioning capabilities that ics, decommissioning security agreements toward the end of can be marketed worldwide as it makes the most of the steady field life, planning the cessation of production and preparing flow of diverse and technically challenging projects on the UKCS. decommissioning plans. The association is using this structured In areas of highly technical complexity like well decommis- approach to set a global performance framework, a valuable sioning, the industry is already delivering projects safely and tool for benchmarking projects. in an environmentally-sound and cost-effective manner. Over In November 2018, the UK government acknowledged the the past year, forecast decommissioning costs per well have industry’s coming of age when it issued a call for evidence on its fallen by an average of 26%. While market conditions played plans to make the UK a global hub for decommissioning. As one a role in these cost reductions, the industry’s improving effi- of the most mature decommissioning markets, the UK can help ciency is helping to deliver repetitive gains in most projects. set the agenda on how these activities are effectively regulated In some individual projects, the average amount of days spent to ensure safety, environmental protection, and sustainability. on well decommissioning have halved throughout the lifecy- The UK’s growing expertise in cost-effective decommissioning cle of the project. combined with a stable fiscal regime is improving the competi- Looking ahead, 1,465 UKCS wells are forecast to be decom- tiveness of the supply chain. With other countries already mov- missioned in the next decade. Representing one-fifth of the total ing to secure a share of global decommissioning work, the call well stock drilled to-date in the UK North Sea, this equates to a for evidence presents the country with a great opportunity to steady stream of almost 150 wells per year on average. focus on the highly specialized areas where the UK excels such These activities will happen across the UKCS with decom- as well decommissioning, removals and subsea infrastructure missioning taking place on 391 wells in the northern North Sea decommissioning and apply these internationally. and west of Shetland; 475 in the southern North Sea and Irish The Oil and Gas Authority’s (OGA) UKCS Decommissioning Sea; and 599 in the central North Sea. Comprising a mixture 2018 Cost Estimate Report highlighted the country’s growing of platform, subsea and suspended exploration and appraisal expertise, showing the industry has already reduced costs by wells, they represent a sizeable quantity of projects where the 7% from the 2017 estimate. UK’s supply chain can both apply and hone its expertise, in The UK government is rightly focused on cost-efficient highly specialized aspects of decommissioning. decommissioning, a desire the industry shares and is com- The association is setting the agenda technically including mitted to deliver in a safe and environmentally responsible

The Work Breakdown Structure provides a standard approach to modeling decommissioning projects. (Courtesy Oil & Gas UK)

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manner. The industry is largely responsible for covering the cost Yet, how do we build on the industry’s decommissioning of decommissioning, which as the 2018 Insight report shows achievements to date, while maximizing economic recovery was £1.15 billion ($1.48 billion) in 2017. These are normally from the UK North Sea? occurring business costs which companies can offset against Education and training are key in helping us build upon the current or historic profits, taking place toward the end of the advanced capabilities that exist in the UK. A growing number lifecycle of an asset. of initiatives are already inspiring, educating, and preparing the Companies’ decommissioning spend provides work for sup- future decommissioning workforce, in response to the broaden- ply chain companies, helps develop highly exportable special- ing awareness that decommissioning has come of age. ist capabilities and in turn, generates tax receipts for the UK In 2017, the University of Aberdeen launched the world’s Treasury. While the industry receives some tax relief on its first MSc in Decommissioning, and Sam George of the Oil & decommissioning costs, Gas UK is one of the first it is only a small fraction students to have earned a of the £330 billion ($424 degree in this pioneering billion) paid in produc- qualification. Designed tion taxes alone to the in collaboration with treasury since North Sea operators, supply chain production began. companies and regula- In 2016, the OGA set tors, it is a positive step the sector a target to in ensuring experience reduce forecast costs by is shared with those who 35% by 2022. The reg- wish to pursue a career in ulator’s Cost Estimate decommissioning. report shows the prog- Elsewhere in Aber- ress toward this goal, deen, Robert Gordon Uni- much of which has been versity offers a course in achieved through bet- ‘Planning for Decommis- ter project planning and sioning.’ Developed with execution. the OGA, the UK gov- New technology has ernment’s Department significant potential to The National Decommissioning Centre in Aberdeenshire launched in January. for Business, Energy and realize efficiencies in (Courtesy Oil & Gas UK) Industrial Strategy, and decommissioning proj- the Health and Safety ect delivery. Created in 2017, the Oil & Gas Technology Centre Executive, this provides students with detailed insight into (OGTC) in Aberdeen is an industry-led research and knowledge decommissioning legislation. organization, backed by the UK and Scottish governments to In January 2019, the National Decommissioning Centre (NDC) fund and direct projects aimed at unlocking the full potential was launched. The author is a member of the steering commit- of the UK North Sea. tee for this new resource in Aberdeenshire, which is the result Decommissioning is one of OGTC’s focus areas and there of a £38-million ($49-million) partnership between the OGTC have been great examples of industry, academia, and govern- and the University of Aberdeen. The goal of the NDC is to be ment collaborating to develop innovative technological solu- the leader in research and development that transforms decom- tions. Spirit Energy, well specialist Interwell, and several major missioning and mature field management. North Sea operators are trialling a new well decommissioning The UK is now well positioned to make the most of a global technology that could cut millions of pounds from budgets. market of some $80 billion over the next decade. The UK oil The new method, being trialled in an onshore well, uses ther- and gas industry is focused on making the most of this unique mite and a controlled chemical reaction in the well rather than window of opportunity. • a traditional cement plug. The UK’s offshore oil and gas industry is setting the agenda THE AUTHOR commercially, with companies combining their strengths to Joe Leask is Oil & Gas UK’s decommissioning deliver broader services to operators. These innovative contract- manager. ing strategies offer operators a variety of options for tendering while also enabling the participation of a greater number of supply chain companies, enhancing competition in the market. Through developing world-leading expertise in decommissioning, the UK industry is unlocking significant potential to export this expertise to other oil provinces.

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Full field development example: FPSO Cidade de Itaguai MV26 offshore Brazil. (Courtesy MODEC) Employing best practices underpins FPSO project success Industry moving toward standard specifications

JEFF DICE, ENDEAVOR MANAGEMENT

THIS AUTHOR’S FIRST FPSO experience began in the Effective use of FPSOs depends upon several key aspects, mid-1990s, and the assignment offered several key lessons. including strategic decisions, project delivery, re-deploy- That first project involved the conversion of an old tanker ment and hull design, process and module design, mooring into an FPSO on an incredibly short schedule. Based on and offloading, and operational considerations. the commercial success of that field, the industry had an opportunity to improve risk acceptance of conversions and STRATEGIC DECISIONS short schedules. More than two decades later, that field is Selection of the FPSO as a development solution has become still producing, and the FPSO industry still has opportunity more widespread, but strategic decisions made in conjunc- for improvement. tion with FPSO concept selection impact a range of perfor- With WTI crude prices fluctuating around $50/bbl, there mance parameters during both project execution and the continues to be a push to advance cost-effective field develop- life of the field. Two of the most important strategic deci- ment options for oil-rich discoveries, and FPSOs have proven sions are definition of: to be effective solutions in a wide range of water depths. • Technical specifications

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• Whether to lease or to own. selection and design. After years of being driven by detailed company specifica- Because they are highly autonomous floating systems, tions developed by major operators with low risk tolerance, FPSOs offer high potential for relatively simple removal and the offshore oil and gas industry is moving to standard indus- relocation compared to most other production system alter- try specifications that may not yet be fully developed. The natives. As examples, the industry’s second FPSO (FPSO II, decision to own or lease an FPSO is affected by a number SBM) is now on its fourth location after an initial 11‐year of factors which include access to cash, cost of financing, deployment and Petrojarl I (Teekay) commenced production expected period of production, and control of operations in May 2018 on its 12th redeployment. with the associated risks. PROCESS AND MODULE DESIGN PROJECT DELIVERY The FPSO industry seems to have settled on common designs Project delivery addresses three major issues associated with for the separation of oil, water, and gas with only a few mod- successful delivery of FPSO projects including: ifications in the basic design to handle unique reservoir con- • Project organization ditions. This leaves the design of the process system on the • Interface management FPSO focused on three major areas: • Change management. • Vapor recovery FPSO projects have distinctive characteristics such as • Gas handling (and disposal) storage and offloading with strong marine industry links • Water treatment/injection. that are significantly different from other floating produc- The global trend toward reducing greenhouse gas emis- tion systems, and which require specific resources and orga- sions has created the need for FPSO operators to develop nization to properly manage and deliver successful projects. and use methods to minimize emissions from vapor recovery, The integration of these resources into the overall project tank inerting, and gas disposition once it has been recovered. team is critical for success in terms of schedule, budget, and In addition, country regulations are becoming more strin- risk management. gent regarding the overboard disposal of process water and Effective management of interfaces is a critical success reducing the acceptable levels of oil in water, as well as factor for delivering any project. The effort required to do regulating other constituents in the produced water dis- this increases exponentially with complexity. FPSOs are on charged to sea. the high end of the complexity spectrum due to the multiple FPSO process module design addresses three major areas functional requirements spread across several contractors associated with the design, installation, and placement of and multiple equipment suppliers. the process system modules on the FPSO. These are: Change during FPSO projects is a given, and failure to • FPSO operability accept, recognize, plan for, and respond to change can be • Crew safety attributed as one of the greatest contributors to adverse • Installation and interfaces considerations between the FPSO project performance. The impacts can be very visi- hull and the process modules, which need to be addressed ble and predictable or hidden and appear indirectly. Most during the design of the FPSO. of these factors have a negative effect on the project cost, outcome, and stakeholder relationships. The development MOORING AND OFFLOADING of a robust change management system is a requirement for Once an FPSO is selected as the field development option, a successful FPSO project. a key decision will be related to the selection of mooring, risers/umbilicals, and associated oil export offloading sys- REDEPLOYMENT AND HULL DESIGN tem. Important considerations associated with this decision A major early decision for the FPSO will be whether the hull include the operational location, disconnect strategy, field is based on a converted tanker or a newbuild FPSO specific architecture and associated turret/fluid swivel system, and design. Conversion is dependent upon availability of a tanker type of export tankers. of sufficient size to meet storage requirements, whereas new- builds may be customized for the application. OPERATIONAL CONSIDERATIONS Whether newbuild or conversion, a suitable FPSO hull Most FPSO operating procedures are similar and can be must account for the required storage volume, cargo/ballast applied to FPSO operation in different locations and under handling systems, topsides weight, weather at location, regu- different jurisdictions. Developing and implementing gener- latory constraints, on‐station repairs and maintenance over ally acceptable standard operating procedures could achieve the full operating life, and tank/skin protective configuration. safer operations, considerable cost savings, greater oper- Class can play an important role in conformance with ational efficiency, uncertainty reduction, savings in time, regulatory and Flag State requirements for an FPSO. A strat- effort and man hours, greater ease of crewmember transfer egy for Class or alternative means of marine assurance and from one FPSO to another, and would result in a reduction marine regulatory approval must be in place as part of hull of operating risks – i.e. improved risk management.

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Marginal field development example: FPSO Ocean Producer offshore Angola. (Courtesy Endeavor Management)

NEXT STEPS Best Practices JIP is currently being offered to the industry. With all these opportunities for improvement, the indus- Although the successful design and implementation of try seems poised to capture FPSO best practices and apply an FPSO on a project is a result of a multitude of decisions them to future projects. These best practices could lead to and tradeoffs for the operator, experience has proven that FPSO industry standards. Having recognized this, Endeavor using lessons from past projects helps successful comple- Management has organized a joint industry project to seek tion of current and future projects. Except for a few major out the best practices for FPSO projects from those with operators and leased FPSO providers, FPSO projects do not the experience to share with the industry. The goal of this come along very often for individual companies, and improv- JIP is to define and organize the best practices across the ing performance is hard to do without some history from participant group and give the participants access to indus- which to learn. Hopefully, the industry can both create and try knowledge and thereby improve industry performance. apply FPSO Best Practices to create competitive projects. • Endeavor has developed a three-stage process that will be applied to this FPSO Best Practices JIP. THE AUTHOR The first stage will gather JIP participant subject matter Jeff Dice, PE, PMP has 28 years of experience experts (SMEs) to input their practices on the topics listed as project manager and structural engineer, here. The second stage will have Endeavor expert advisors providing field development, project manage- compile and delineate the practices for all topics and pres- ment, design assurance, structural analysis ent back to participant SMEs for review. The third stage will and design, fabrication support, installation be creation of a report across all topics in a form as will be management, planning/scheduling, and cost useful for future participant use. Using this kind of in-depth estimation for FPSO and other offshore projects. knowledge along with early engineering, operators can significantly improve perform FPSO project outcome. This FPSO

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1903OFF35-37.indd 37 2/28/19 4:03 PM • PRODUCTION OPERATIONS Eider bypass project extends lives of North Sea fields Production platform converted to new service role

JEREMY BECKMAN, EDITOR, EUROPE

NORTH SEA OPERATORS are striving to extend the lives (12,793 tons). The original plan called for seven production and of their older facilities. TAQA’s Eider platform, installed in the seven water injection wells, with 10 spare well slots on the jacket late 1980s, had reached the point where running costs were too in case further wells needed to be drilled through the heavily high to justify continued tail-end production from Eider and faulted mid-Jurassic Brent Group reservoir. further hosting of the Otter field subsea tieback. But by re-rout- Development also entailed extensive use of existing facilities ing Otter’s oil and converting the platform to a new utility role, at the partners’ nearby Cormorant and Tern field platforms. So the company has managed to defer full-scale decommissioning the Eider facility was designed for separating water from the until well into the 2020s. production stream (first-stage separation) with oil and gas Shell and partner Esso discovered Eider in 1976 in block sent to North Cormorant for processing, while injection water 211/16 in the UK northern North Sea, in a water depth of 158 m would be imported from Tern. Eider’s produced gas was used (518 ft). The fixed steel platform, built in Nigg, northeast Scot- for power at the platform, with surplus power and gas sent to land, comprised an 18,670-metric ton (20,580-ton) jacket and North Cormorant. North Cormorant and Eider are connected a 5,557-metric ton (6,125-ton) integrated deck – reportedly the via a 33-kV subsea cable allowing power sharing between the first ever for a North Sea oil platform – supporting derrick, drill- two assets; generators on Eider and North Cormorant can gen- ing and accommodation modules, a flare boom and helideck erate power from process gas or diesel. totaling an overall dry topsides weight of 11,606 metric tons As Eider’s oil production started to decline, capacity became

Area map. (All images courtesy TAQA)

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available on the platform for a subsea tieback of the Otter oil field, 21 km (13 mi) to the northwest, which operator Total developed in the late 1990s via three oil production wells fitted with dual electric submersible pumps, with Tern providing injection water for reservoir support. During the following decade, Shell, like other major oil companies in the area, decided to downsize in the UK North Sea, and this led to Abu Dhabi National Energy Company PJSC (TAQA) assum- ing operatorship in 2008 of Eider, Cor- morant Alpha, North Cormorant, Tern, and associated subsea fields. In 2012 the company negotiated a separate deal with Total that gave it full ownership of Otter. Between 2009 and 2017 TAQA reac- tivated the Eider platform’s drilling rig, The new multi-phase pump designed and constructed by OneSubsea for the Otter field for extended the accommodation, replaced the bypass project. the water injection and production flowlines between Eider and Otter, and carried reserves of 6.6 MMbbl, lifting the total anticipated recovery to 87 MMbbl. “In fact out obsolescence and maintenance proj- Eider’s production has been significantly better than estimated in the two FDPs,” ects on the platform to ensure continued Gibson said, “with the field delivering 118 MMbbl from the latest resource estimate economic and safe operation. “The facil- of 240 MMbbl, a recovery factor of around 49%. ity remained essentially as it was installed “However, by late 2017 the well delivery rate was at a level where production was with the addition of some further accom- uneconomic and the combined opex across North Cormorant, Eider, and Tern would modation modules, through 2017,” said have rendered the entire area uneconomic if we had done nothing. In addition, there Technical Director David Gibson. “Other were integrity issues with the water injection and production pipeline risers at Eider. than maintenance and some obsoles- By fully bypassing Eider, TAQA calculated that the integrity threat could be fully mit- cence changes, Otter system support or igated and opex reduced across the field.” utilities have also remained as they were The project involved a series of measures including: P&A of all 18 Eider platform when TAQA took over operatorship. wells, with removal of all conductors – completed January 2019; bypass of hydro- “During the period to 2017, the com- carbon and water injection pipelines – completed September 2018; installation of a pany completed well interventions and multiphase pump at Otter – completed September 2018; and flushing and purging scale squeezes to maintain safe produc- of hydrocarbons and make-safe modifications on Eider – scheduled to be completed tion on the Eider and Otter wells. Subsur- in April 2019. face studies were carried out, but these Gibson explained: “The Eider platform was engineered to be remotely controlled did not identify further economic infill via a microwave link from North Cormorant, although Shell’s goal of sustained fully targets. On Otter, the company com- remote operation was not achieved. Under the bypass program only minor changes missioned workovers to replace a failed were necessary to the control systems so that Otter could be controlled directly from electric submersible pump and dive sup- North Cormorant. Otherwise, the remote control arrangement remains basically the port vessel campaigns to rectify subsea same as in the original design. infrastructure issues and production “There has been no need for structural strengthening on the Eider platform, and was maintained through scale squeeze no equipment has been removed as yet. Maintenance has been significantly reduced activities.” as the platform is fully isolated from wells and pipelines. However, structural inspec- When Eider came onstream in Novem- tion will continue and any improvements to equipment performance arising from ber 1988, estimated in-place oil, accord- advances in digital techniques will be applied to Eider, as it would to the rest of the area. ing to the field development plan (FDP), “A very small crew remains, charged with maintaining the utility systems that pro- was 204 MMbbl with targeted production vide power and utilities to Otter and power sharing for North Cormorant, enabling over the life of the field of 85 MMbbl, a maintenance on that facility. We may also use Eider to demonstrate alternative removal recovery factor of 42%. Shell later issued methods and will consider any re-use opportunities for the asset.” an addendum to the FDP extending pro- In the platform’s new utility mode, Otter production continues and with the lat- duction to the Eider West area, where ter’s recently installed multi-phase pumping system, output is now higher as the sys- the target was 2 MMbbl from estimated tem enables concurrent production from all the field’s three oil wells. In addition,

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The Eider platform.

production reliability is increased and assured as the design life strategy of maximized economic recovery from its assets in of the multiphase equipment is greater than that of the existing the UK northern North Sea. This is the company’s first use of electric submersible pumps. MPP technology in the North Sea, and the investment not only “As for North Cormorant,” Gibson said, “only minor changes extends the producing life of Otter, thereby helping to prolong needed to be made to existing equipment in order for the plat- the life of the host North Cormorant platform, but also creates form to receive and meter the multiphase fluids from Otter. On a window of opportunity for the company to pursue new devel- Tern the water injection system was modified to provide pres- opment prospects at North Cormorant. sure protection to the Otter flowline, a task that was previously Contractor OneSubsea performed design, testing, installation handled from Eider.” and commissioning of the pump within 16 months, with the Following the changes, TAQA expects the Eider platform total project management model fulfilling both parties’ goal of to remain in utility mode into the next decade and for North improved execution efficiency. Project manager Derek Pullem Cormorant to keep producing until at least 2024. However, the commented: “It was critical for us to perform the project when company is keeping its options open for the area’s longer-term we did – and within the set timescales – to maintain the viabil- future. “Cessation of production [CoP] of any asset is some- ity of the overall strategy. Delivery has been closely interlinked thing that is reviewed on a regular basis,” Gibson explained. with other strands of the strategy to help us achieve our overall “Within TAQA’s UK northern North Sea portfolio there remain production goals. If we’re to make the most of our aging assets a number of opportunities that could bring greater value and/ that is the kind of creative approach we’ll need to take in future.” or change the CoP date. These assets remain open to new busi- The program involved sustained support from TAQA’s off- ness opportunities.” shore personnel and close working links between installation contractor Subsea 7, Eider and North Cormorant during the OTTER FIELD LIFE EXTENSION final phases. With three Otter wells producing simultaneously, The start-up in late October last year of a multi-phase pump production from the Otter field has increased by around 3,000 (MPP) in the Otter field marked another milestone in TAQA’s b/d compared to levels in 2017. •

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1903OFF38-40.indd 40 2/28/19 4:03 PM SUBSEA • Industry advances ROV and AUV technologies New subsea robotics maximize uptime

JESSICA STUMP, ASSISTANT EDITOR

AS THE OFFSHORE oil and gas industry recovers, demand according to the analyst’s World AUV Market Forecast 2018- for remotely operated vehicles (ROV) autonomous underwater 2022. The benefits of using AUVs for field inspection go beyond vehicles (AUV) increases. cost savings, said Westwood analyst Ian McDonald. They can Global utilization of the available ROV fleet fell to 32% in 2017, increase operational safety, lessen the environmental impact according to Westwood’s latest World ROV Operations Market of inspection operations, and reduce the number of personnel Forecast. However, demand for both traditional oil and gas appli- needed at sea. cations and new offshore support roles will assist a recovery in As operators look to sustain capital discipline, ROV and ROV demand between 2019 and 2023. The analyst expects that AUV manufacturers are responding with new systems that with upcoming attrition in the fleet and an improved demand maximize uptime. outlook, utilization could return to 50% by 2023. Houston Mechatronics has introduced Aquanaut, a multi-pur- As operators continue to move into deeper waters, West- pose subsea robot which employs a patented shape-shifting wood anticipates a notable uptake in AUV utilization transformation from an AUV to an ROV. The vehicle, which for oil and gas operations. More offshore operators look removes the need for vessels and tethers, is said to enable both set to deploy AUVs for life of field inspection programs, the efficient collection of data over long distances as well as manipulation of subsea objects at a lower cost than today’s technology. As an AUV, the Aquanaut can cover up to 200 km (108 nautical mi) in one mission and features vertical thrust control and an articulating bow. The company said it transforms into an ROV with four in-house designed linear actuators. The hull separates in one fluid motion, expos- ing two more control thrusters,

The Aquanaut transforms from an AUV to an ROV. (Courtesy Houston Mechatronics)

MARCH 2019 OFFSHORE | WWW.OFFSHORE-MAG.COM 41

1903OFF41-43.indd 41 2/28/19 4:03 PM MultiBooster | 6 MW for Increase production. Now. Maximized Production TechnipFMC delivers subsea boosting solutions that improve return on investment, Qualiﬁed subsea boosting solution 250 bar pressure increase at 60% GVF achieve recovery faster and enhance production that is reliable, sustainable Enabler for deeper water and longer tie-backs and economical through the life of the field.

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AkerSol_OSmaps_1903 1 2/18/19 10:58 AM Intecsea_OSmaps_1903 1 2/20/19 11:58 AM Technip_OSmaps_1903 1 2/18/19 10:56 AM SUBSEA SEPARATION SYSTEM TYPES: Fig. 2: TechnipFMC Conceptual SS Gas/Liquid Fig. 4: Saipem Multipipe Fig. 5: Aker Solutions subsea oil/water SUBSEA SEAWATER TREATMENT AND INJECTION SUBSEA BOOSTING PUMP TYPES BOOSTING SYSTEM EXAMPLES (CONCEPTUAL & DELIVERED) Fig. 5: Saipem/Curtis Wright Separation & Boosting System for Pazflor (Prototype Tested 2-phase separation and injection, featuring 1st and GRAPH 1 – GVF vs. DIFFERENTIAL PRESSURE - OPERATIONAL AND CONCEPTUAL CAPABILITIES GRAPH 2 – DIFFERENTIAL PRESSURE vs. THROUGHPUT - SUBSEA PUMP CAPABILITIES Injection Pump 350 350 Gas/liquid Separation and 2nd stage separation, oil boosting and water Fig. 1: Aker Solutions’ Fig. 2: Conceptual Illustration Fig. 3: Subsea water injection COURTESY OF Fig.1: Installation of the Fig. 2: OneSubsea’s Pump Fig. 3: OneSubsea’s Helico- Fig. 4: OneSubsea’s Centrifugal Pump 2019 WORLDWIDE SURVEY TABLE 2 – PUMP TYPES & APPLICATIONS 5,100 5,100 1. GRAVITY SEPARATION SYSTEMS Fig. 3: GE Subsea Separation and Produced Water Boosting System) injection pumps LiquidBooster™ Subsea Raw of Installation of Tyrihans integrated solution - Aker OneSubsea Pump Module Station with Pump Unit and Axial Pump Module for the Module with handling tool during SIT SPP - Single Phase Pump Fig. 1: TechnipFMC Subsea Separation System for the Tordis Project. Reinjection System for Troll C Seawater Injection (SRSWI) SRSWI System Solutions LiquidBooster™ TYPE NORM. CONFIG. APPLICABILITY FOR SUBSEA BOOSTING 300 300 SPP - Single Phase Pump into Pump Station during Mixer for CNR’s Lyell project Total GirRi project for the Exxon Julia project System for Statoil Tyrihans and NOV 4,400 SPP (Centrifugal) TSP - Twin Screw Pump 4,400 MPP - Multi-Phase Pump SIT for Exxon Julia OF SUBSEA PROCESSING H Highest differential pressure capability among pump types WGC - Wet Gas Compression SPP ESP - Electrical Submersible Pump CENTRIFUGAL HORIZONTAL 250 H Handles low Gas Volume Fraction (GVF) < 15% at suction 250 (SINGLE PHASE) OR VERTICAL 3,625 DGC - Dry Gas Compression 3,625 conditions Helico-Axial STATUS OF COMPLEMENTARY TECHNOLOGIES AND SYSTEMS H Combination of helico-axial and centrifugal impeller stages 200 200 H Primarily used downstream of separator or in low GOR 2,900 2,900 HYBRID VERTICAL applications where GVF is consistently < 30% at suction 150 Hybrid 150 MARCH 2019 conditions 2,175 2,175 H Widely deployed technology used for boosting individual 100 TSP 100 Courtesy of Saipem/ Curtiss Wright HORIZONTAL wells, caissons, flowline risers, and mudline horizontal Prepared By: John Morgan, Lee Thomas, Terry Wood, Matai Wilson, MUDLINE ESP 1,450 1,450 OR VERTICAL boosting applications ESP MPP Courtesy of OneSubsea Sriram Subramanian, Mac McKee, and Rebecca Roth of INTECSEA, Courtesy of Aker Solutions Courtesy of Aker Solutions NOV and Aker Solutions H Tested for conditions up to 70% GVF 50 50 Courtesy of OneSubsea Courtesy of OneSubsea Fig. 10: Seafloor Boosting 725 725 Fig. 9: TechnipFMC MPP Using ESP in Caisson

H Applicable for higher GVF boosting applications; Capable of Differential Pressure (Bar or psi) WGC DGC Differential Pressure (Bar or psi) Courtesy of BHGE, a GE company Fig. 4 & 5: Saipem-Veolia-Total Subsea Fig. 6: NOV’s Seabox™ subsea water treat- HELICO-AXIAL operating at 0-95% GVF at suction conditions Fig. 7: GE Boosting Station Fig. 8: OneSubsea’s Pump Modules for for BC-10 E. Kurt Albaugh, Consulting Engineer & Volunteer Poster Editor, Courtesy of Aker Solutions VERTICAL 0 bar 0 bar Courtesy of OneSubsea Sulphate Removal Prototype - deep water ment module for disinfection and particle (MULTIPHASE) Most common subsea multiphase pump type 0 psi 0 psi Total GirRi and Shell Draugen prior to SIT Courtesy of Saipem H 0 10 20 30 40 50 60 70 80 90 100 0 m3/Day 66 133 199 264 331 397 464 530 596 662 and David Davis of Offshore Magazine tested at Alima FPU in Congo; whole system settlement for optimizing water injection. H Moderate particulate tolerance 0 MBLPD 0.42 0.84 1.25 1.66 2.08 2.50 2.92 3.33 3.75 4.16 Fig. 6: TechnipFMC % GVF LIQUID GAS Poster Assembled By: Chris Jones of Xenon Group, Inc. Courtesy of TechnipFMC Fig. 7: Saipem SpoolSep (Laboratory Tested 3-phase industrialization is ongoing; unit capable of H Good for handling high GVF - up to 98% GVF at suction Throughput (m3/Day or MBLPD) SS Multiphase Pumping Separation and Produced Water Reinjection System) treating and injecting up to 80 kbwpd TWIN SCREW HORIZONTAL conditions Notes: 1. For pump applications, the term differential pressure is used. However, for Module with Sulzer Pump Fig. 8: NOV Produced Water Separator – meeting Notes: Curves are approximate and assume a specific liquid throughput, identical for each E-Mail Comments, Correction or Additions to: [email protected] (MULTIPHASE) OR VERTICAL H Preferred technology for high viscosity fluids. Less efficient compressor applications the term pressure ratio is used. 2. Curves are approximate and COURTESY OF COURTESY OF Fig. 6: Aker Solutions’ Hi-Sep, a robust and flex- strict reservoir injection or discharge requirements at lower viscosities. assume a specific liquid throughput, identical for each pump type. pump type. Values are given on a “per pump” basis. For Archived SS Processing Posters: http://www.offshore-mag.com/maps-posters.html Courtesy of TechnipFMC ible solution for CO2 separation and re-injection by gravity based produced water cleaning For Educational Videos on SS Processing: http://www.offshore-mag.com/learning-center.html HORIZONTAL SEPARATOR - This type is more efficient for oil/water separation. An example is the horizontal VERTICAL ESP PUMPS SINGLE PHASE PUMPS (CENTRIFUGAL) HYBRID PUMPS MULTIPHASE PUMPS TWIN SCREW PUMPS separator for the Tordis Project shown in Fig. 1 above. HORIZONTAL/MUDLINE ESP SYSTEM EXAMPLES Courtesy of GE (For GVF < 70%) (For GVF < 15%) (For GVF < 30%) (HELICO-AXIAL/ROTODYNAMIC) (For GVF < 95%) (For GVF < 98%) Courtesy of OneSubsea Courtesy of TechnipFMC Fig. 11: Jack & St. Malo Pump VERTICAL SEPARATOR – This type is more efficient for gas/liquid separation. The liquid keeps a fluid blanket on Fig. 1: Diagram of Vertically Fig. 2: Horizontal ESP Boosting Station the pump and reduces potential pump cavitation. An example is the Pazflor vertical separator shown in Fig. 2. Fig. 4: Vertically Configured Fig. 5: Vertically Configured Fig. 6: Vertically Configured Fig. 7: Vertically Configured Fig. 8: Vertically Configured Fig. 9: Vertically Configured Fig. 10: Twin Screw Pump Cross Stations in the Factory Pit for SIT Fig. 12: OneSubsea’s SIT Testing of Fig. 13: Aker Solutions Configured Gas Handling ESP Centrifugal Single Phase Centrifugal Single Phase Hybrid Pump & Motor Hybrid Pump & Motor Helico-Axial Pump & Motor Semi-Axial Pump Section Diagram Total MoHo Subsea Boosting System MultiBooster™ System - in a Seabed Caisson Courtesy of Saipem Courtesy of NOV Pump & Motor Diagram Pump & Motor Diagram Diagram Diagram Diagram Pump & Motor Diagram Dual Pump Station 2. CAISSON SEPARATION Fig. 10: Caisson Separation/ Fig. 11: TechnipFMC ESP Boosting System Vertical Access Caisson Fig. 8: NOV’s SYSTEMS INSTALLED Fig. 7: BHGE conceptual SWIT™ subsea Courtesy of Aker Solutions MAGAZINE with ESP Boosting Courtesy of Aker Solutions Courtesy of Saipem Courtesy of NOV (Gas/ Liquid Separation & Subsea Sulphate Removal water treatment < 100m INTO SEABED Fig. 14: Åsgard Single Boosting System) and Injection System, built on technology for 3. COMPACT/DYNAMIC SEPARATION SYSTEMS a combination of ultra-and tailored water Phase Pump INTECSEA, Inc. Offshore Magazine Fig. 15: ExxonMobil’s SS Compact Separation, nano-filtration technologies, quality at seabed Fig. 12: OneSubsea Conceptual Fig. 13: OneSubsea Conceptual Fig. 14: TechnipFMC 3-Phase Separation Boosting, and Produced WI System Using for IOR / EOR. Courtesy of Sulzer/ 575 North Dairy Ashford St 1455 West Loop South, Suite 400 scalable to any capacity TechnipFMC Two-Phase Separation System Three-Phase Separation System System with Produced WI Using In-Line Multiple Technologies for 3-Phase Separation Courtesy of NOV Courtesy of OneSubsea Houston, TX 77079 USA Houston, TX 77027 USA Separation Technology for the Marlim Project plus Sand Courtesy of OneSubsea Fig. 9: Centrifugal Subsea Submersible Fig. 15: BHGE Pump Rack Fig. 10: OneSubsea’s Test- Courtesy of Leistritz Fig. 16: TechnipFMC Courtesy of Aker Solutions Tel: 281-987-0800 Tel: 713-621-9720 Pump (BCSS) Fig. 17: Loadout of the ing of the Albacora Raw Courtesy of TechnipFMC Centrifugal Pump Station OneSubsea Pump Station for Fig. 18: OneSubsea – Loadout of 1 of 6, www.intecsea.com www.offshore-mag.com Seawater Injection System Fig.11: BHGE Modular Compact Pump with Multiphase Pump the Total CLOV Project 2.3MW Hybrid Pumps for Pazflor during SIT of Pump and Fig. 3: POWERJump Boosting System Cross Section Filtration System ACKNOWLEDGEMENT OF THE CONTRIBUTORS INTECSEA and Offshore Magazine wish to acknowledge the following companies and individuals who continue to support our efforts to educate and inform the oil & gas industry on the status of subsea processing technologies and systems: Courtesy of Aker Solutions Courtesy of BHGE, a GE company ABB: Rita-Wei Fu, Tor-Eivind Moen; ABS: Smarty John, Jessie Lin, Meng-Lung Liu, Hao Song; Aker Solutions: Marco Gabelloni, Jonah Margulis, Kate Winterton; Equinor: Ole Økland; Fig. 22: FSubsea's FSubsea: Alexander Fuglesang; Baker Hughes, a GE company: Alisdair McDonald; ITP InterPipe: Géraldine Salque, Wayne Grobbelaar; ITT Bornemann: Stefan Ladig; Leistritz: George Courtesy of Schlumberger Omnirise Pump - Barrier Tarry; MAN Diesel & Turbo: Roberto Rubichi, Domingo Fernandez, Claudine Bargetzi; Nexans: Angéline Afanoukoe; NOV: Grace Bull, Eirik Dirdal, Wouter Van Korven; OneSubsea: Thomas Fig. 9: OneSubsea Raw Seawater fluid less & integrated Injection System being installed Kajander, Phillip Luce, Grant Harris, Lisa Ann Hofmann; Saipem: Alessandro Radicioni, Stephanie Abrand, Chiesa Giovanni, Casotto Marco, Astrid Engesland; Schneider Electric: Kristina Hakala; Courtesy of TechnipFMC Courtesy of OneSubsea Courtesy of OneSubsea ESPs can be installed in a caisson VSD function (1.5 MW, for Columbia E Field to gather and boost flow from Courtesy of BHGE, a GE Shell: Chris Shaw; Siemens: Richard Barratt, Kim Smith; Subsea 7: Michael Firmian, Guy Mencarelli, Sigbjorn Daasvatn, Martin Goodlad; Sulzer: Mika Tienhaara; TechnipFMC: Janardhan Courtesy of Aker Solutions Courtesy of BHGE, a GE company Figs. 2 & 3: Courtesy of OneSubseaCourtesy Courtesyof TechnipFMC of OneSubsea CourtesyCourtesy of OneSubsea of ExxonMobil Courtesy of Aker Solutions 6600V SPP prototype) Davalath; Teledyne: Justin Kretschmar; Voith: Thomas Taeuber Courtesy of OneSubsea Courtesy of OneSubsea multiple wells. Courtesy of Aker Solutions Courtesy of OneSubsea Courtesy of Aker Solutions Courtesy of OneSubsea Courtesy of Aker Solutions Courtesy of OneSubsea Courtesy of Aker Solutions Courtesy of BHGE, a GE company company Courtesy of TechnipFMC Courtesy of OneSubsea Courtesy of OneSubsea Fig. 19: Seafloor Boosting System Using Fig. 20: Aker Solutions Fig. 21: BHGE Modular Compact COURTESY OF SUBSEA BOOSTING PROJECT TRENDS POSTER COLOR CODE KEY INDUSTRY GUIDELINES FOR SUBSEA PROCESSING – EXISTING & PENDING TABLE 1 – 2019 WORLDWIDE SURVEY OF SUBSEA GAS COMPRESSION & PROCESSING , BOOSTING, WATER INJECTION AND SEPARATIONS (AS OF FEB., 2019), See Notes: (1) & (2) GRAPH 6: SUBSEA SHAFT POWER vs. TIME FOR SS BOOSTING SYSTEMS (As of Feb., 2019) ESPs in Caissons Pump Module Pump (MCP) Dual Booster Station The poster is divided into distinct sections and 1. API 17X – API 17X is expected to have a re-ballot in 2019. Possible release in late 2019 or early 2020.

3.5 each section is marked by a background color. The 2. The DNV Subsea Processing Guideline is planned to be published in 2019. GRAPH 3: TIEBACK DISTANCE vs. WATER DEPTH FOR SS BOOSTING SYSTEMS (As of Feb., 2019) Moho Phase 1bis color denotes the type of technology presented in 3. ABS Guide for Classification and Certification of Subsea Production Systems, Equipment and Components with new SS Pumps - Conceptual (5) IN-SERVICE/OPERATING 0 (ft) Jack & Julia the section. This color code is carried throughout subsection on boosting systems, to be published in 2019. FIELD OR PROJECT CURRENT OWNER/ REGION/ WATER TIEBACK SYSTEM FLOW RATE DIFFERENTIAL SYSTEM NO. OF PUMP TYPE or COMPRESSOR/PUMP Prezioso 3.0 SS Pumps - Awarded and in St. Malo COMMENTS (3) INFORMATION 0 (m) Brenda/Nicol Otter

(Ordered by Start Date) FIELD OPERATOR BASINS DEPTH DISTANCE (@LINE CONDITIONS) PRESSURE PACKAGER PUMPS UNITS COMPR. TYPE MANUFACTURER Shallow the poster. Below are the color code designations 4. ABS’s “Subsea Processing System Advisory”, Updated in August, 2018. Document can be downloaded as a PDF from: COUNT Gulfaks Asgard Manufacturing or Delivered (GVF) DEMAND (As of Mar. 1, 2019)

FRACTION Vigdis Greater Enfield for each of the seven themes. https://ww2.eagle.org/content/dam/eagle/advisories-and-debriefs/sprs-advisory-2018.pdf. DISCIPLINE

UNIT POWER SS Pumps - Operational PROCESSING 1,640 (ft) GAS VOLUME TOTAL POWER TOTAL Vincent Topacio 5. ABS Subsea Inspection, Maintenance and Repair Advisory, to be published in 2019. CURRENT STATUS 500 (m) 2.5 Rosa/Girassol Ceiba C3 & C4 Ceiba FFD Full Wellstream Subsea Boosting Dalmation 3 MBOPD START (12) END or Barracuda Greater Enfield CLOV Vigdis COMPANY Meters Feet Km Miles M /Hr. (37) BAR (4) PSI (4) MW MW % OF VOL. COMPANY PUMPS or COMPR. TYPE COMPANY MTHS 3,280 (ft) MBWPD (Month-Year) PRESENT (m) Subsea Separation 1,000 (m) CLOV 2.0 Parque Das SUBSEA GAS PROCESSING TECHNOLOGIES 1 DEMO 2000 A Equinor K-Lab Test Equinor Offshore Norway 3.60 n/a OneSubsea Counter Axial OneSubsea 2001 Jubarte Jubarte Ph. 2 Conchas MPP Vincent Subsea Gas Compression 2 Ormen Lange Gas Compression Pilot A Testing 1 train @ Nyhamna, Norway Norske Shell Offshore Norway 10 33 0.0 0.0 25,000 3,776 60.0 870 12.50 58.00 n/a Aker Solutions 1 Centrifugal GE Compr/Aker Pump 2011 30-Aug-16 Rosa/Girrasol Courtesy of BHGE, a GE company FOR LONG DISTANCE TIEBACKS 4,920 (ft) Courtesy of Aker Solutions Courtesy of BHGE, a GE company Courtesy of FSubsea Golfinho BCSS Dalmation Water Injection with Subsea Pumps 3 Åsgard - Midgard & Mikkel Fields (7) O Subsea Gas Compression Equinor (18) Offshore Norway 300 984 40.0 25.0 20,000 3,021 50.0 725 11.50 24.40 n/a Aker Solutions (11) 2+1 Spare +1 Centrifugal MAN compr/Aker pump 6-Sep-15 1-Mar-19 41.7 1,500 (m) Golfinho Field Caissons 1.5 King GRAPH 8 – TIEBACK DISTANCE VS. WATER DEPTH FOR SUBSEA GAS PROCESSING OPTIONS 4 Gullfaks South Brent (25) O Subsea Multi-Phase Gas Compression Equinor (18) Offshore Norway 135 443 15.5 9.7 9,600 1,450 30.0 435 5.00 10.00 95% OneSubsea (10) 2+1 Spare Counter Axial OneSubsea 15-Jul-17 1-Mar-19 19.5 Marlim Ceiba (FFD) Subsea Active Heating 6,560 (ft) 0 m 5 Ormen Lange Gas Compression Phase 3 (28) C Subsea Gas Compression Norske Shell Offshore Norway 860 2,822 120.0 75.0 TBD TBD TBD TBD TBD n/a TBD 2 TBD TBD 2021 For a list of worldwide Active Heating projects: www.offshore-mag.com/maps-posters.html 0 (ft) 2,000 (m) 1.0 ACTIVE HEATING SYSTEM TYPES PDG Parque Das Conchas Jack & St. Malo Julia Power Transmission/Distribution and Controls 6 Peon (35) P/H Subsea Gas Compression Equinor Offshore Norway 385 1,263 TBD TBD TBD TBD Deepwater 500 TopacioField (ft) WGC 8,200 (ft) TYPE 1A: Direct Electrical Heating (DEH) – Wet insulated rigid pipe with piggyback power cable 1,640 7 Snohvit C Subsea Gas Compression Equinor Barents Sea 345 1,132 143.0 89.4 TBD n/a TBD TBD 2020

Miscellaneous Information/Combination of Technologies DGC - Dry Gas Compression Depth Feet/ Water Cascade & Chinook DGC SUBSEA GAS 2,500 (m) 1,000 8 Åsgard Phase 2 C Subsea Gas Compression Equinor (18) Offshore Norway 300 984 40.0 25.0 12,000 60.0 11.50 24.40 n/a TBD 2+1 Spare +1 Centrifugal MAN compr/Aker pump 2021 0.5 Fig. 1: Aker Solutions DEH Cable & Attachment to Flowline COMPRESSION & PROCESSING (36) 3,280 9 C Subsea Gas Compression Chevron W. Australia 1,350 4,429 143.0 89.4 Aker Solutions Centrifugal MAN compr/Aker pump Mid-2025 (MW) Subsea Pump Shaft Power Jansz-Io Subsea Compression Project 9,840 (ft) Stones SS Boosting - Awarded and in Manufacturing/Delivered Montanazo & Lubina 1,500 3,000 (m) Fig. 2: Nexans Conceptual DEH Cable Cross-sections & Attachments 10 Multiple Stranded Gas Fields C Pseudo Dry Gas System / OGTC (38) OGA / Various UK, North of Shetland 1,650 5,413 200 124 15,000 2,250 70-90 1,015-1,305 0.3/0.05 0.35 95% TBD 4 mini & (1main+1spare) Centrifugal SSP FSubsea TBD SS Boosting or Compression - Operational 0.0 TABLE 3 – ACRONYMS & 4,920 WGC - Wet Gas Compression ABBREVIATIONS 2,000 1 Prezioso A MPP at Base of Platform ENI Italy 50 164 0.0 0.0 65.0 10 40.0 580 0.15 30-90% Saipem 1 Twin-Screw Nuovo Pignone (9) 1994 1995 11,480 (ft) 1995 2000 2005 2010 2015 2020 2025 DEH riser cable 6,560 PDG - Pseudo Dry Gas 2 Draugen Field A Hydraulic Drive MPP (17) Norske Shell Offshore Norway 270 886 4.0 2.5 193.0 29 50.0 725 0.75 42% OneSubsea 1 + 1 Spare SMUBS, 1-MPP SPX ClydeUnion Nov-95 15-Nov-96 12.2 3,500 (m) Present Ultra Deepwater Ultra 0 (mi) 5 10 15 20 25 30 35 40

AC Alternating Current Depth m/ Water 2,500 3 Lufeng 22/1 Field A Tieback to FPSO Equinor South China Sea 330 1,083 1.0 0.6 675.0 102 35.0 508 0.40 3% OneSubsea / TechnipFMC 5+2 Spare Centrifugal (SPP) OneSubsea Jan-98 15-Jul-09 138.0 US MMS Definitions: 0 (km) 3.1 6.2 9.3 12.4 15.5 18.6 21.7 24.9 Year 8,200 ASD Adjustable Speed Drive 4 Machar Field (ETAP Project) A Hydraulic Drive MPP BP UK North Sea 85 277 35.2 21.9 1,100.0 166 22.0 319 0.65 64% OneSubsea 2+1 Spare Helico-Axial OneSubsea Oil Subsea Tiebacks: Short Conventional Long Distance Tieback (LDT) COURTESY OF 3,000 Armored BCSS Centrifugal Subsea Submersible Pumps DEH riser cable 9,840 5 Topacio Field O 1 x Dual MPP System ExxonMobil Equatorial Guinea 550 1,805 8.0 5.0 940.0 142 35.0 508 0.86 75% OneSubsea 2+1 Spare Helico-Axial OneSubsea Aug-00 1-Mar-19 197.1 Gas Subsea Tiebacks: Short Conventional Long Distance Tieback (LDT) feeder cable BPD Barrels per Day 0 (km) 100 125 150 175 200 (for heating one or 0 (mi) 62.1 (mi) 77.7 (mi) 93.2 (mi) 108.7 (mi) 124.3 (mi) 6 Ceiba C3 + C4 O Phase 1 SS MPP Project Triton Energy (HESS) Equatorial Guinea 750 2,461 7.0 4.3 600.0 91 45.0 653 0.85 75% OneSubsea 2+1 Spare Helico-Axial OneSubsea Oct-02 1-Mar-19 171.1 Feeder cable BOPD Barrels of Oil per Day GRAPH 7: WATER DEPTH vs. INSTALLATION YEAR FOR SS BOOSTING SYSTEMS (As of Feb., 2019) two segments) Piggyback Tieback Distance km/(miles) COURTESY OF 7 Jubarte EWT A Riser lift to Seillean drillship Petrobras Espirito Santo Basin 1,400 4,593 1.4 0.9 145.0 22 140.0 2,000 0.70 22% TechnipFMC 1 ESP Schlumberger (REDA) Dec-02 1-Dec-06 47.9 Tieback Distance Miles/(km) BWPD Barrels of Water per Day 0 (ft) Gulfaks cable 8 Ceiba Field (FFD) O Full Field Development (FFD) Triton Energy (HESS) Equatorial Guinea 700 2,297 14.5 9.0 2,500.0 378 40.0 580 1.20 75% OneSubsea 6+ 2 Spare Helico-Axial OneSubsea Dec-03 1-Mar-19 157.1 Prezioso Otter CAPEX Capital Expenditure COURTESY OF 0 (m) Mutineer/Exeter Brenda/Nicole Asgard Shallow Draugen 9 Mutineer / Exeter O 2 x Single MPP Systems Santos NW Shelf, Australia 145 476 7.0 4.3 1,200.0 181 30.0 435 1.10 0-40% OneSubsea 2 MPP Helico-Axial OneSubsea (16) Mar-05 1-Mar-19 142.1 Schiehallion Vigdis DC Direct Current 1,640 (ft) Lufeng 22-1 Topacio Vincent Junction box Piggyback cable GRAPH 9 – GVF VS. DIFFERENTIAL PRESSURE FOR SUBSEA GAS PROCESSING OPTIONS 10 Lyell (Original Install) A SS Tieback to Ninian South CNR UK North Sea 146 479 15.0 9.3 1,100.0 166 18.0 261 1.60 40-70% Aker Solutions 1 Twin Screw Bornemann SMPC 9 Jan-06 Dec-06 11.0 Ceiba FFD DEH Direct Electrical Heating 500 (m) 120 11 Navajo I, N ESP in Flowline Riser Anadarko US GOM 1,110 3,642 7.2 4.5 24.0 4 40.2 583 0.75 57% Baker Hughes 1 ESP Baker Hughes Feb-07 1-Aug-07 5.5 GRAPH 4: TIEBACK DISTANCE vs. TIME FOR SS BOOSTING SYSTEMS (As of Feb., 2019) Greater Enfield DGC Dry Gas Compression Ceiba C3 & C4 PDG 12 A Seabed ESP-MOBO, Uses BCSS (14) Petrobras Espirito Santo Basin 1,350 4,429 4.0 2.5 120.0 18 138.0 2,002 0.90 10-40% TechnipFMC 1 ESP Schlumberger (REDA) Mar-07 Aug-07 5.0 3,280 (ft) Barracuda Who Dat EFL Electrical Flying Lead Jubarte Field - Phase 1 (m) 100 40 1,000 (m) Jubarte Ph. 2 WGC 13 Brenda & Nicol Fields O MultiManifold with 1 MPP Premier Oil UK North Sea 145 476 8.5 5.3 800.0 121 19.0 276 1.10 75% OneSubsea 1+1 Spare Helico-Axial OneSubsea Apr-07 1-Mar-19 117.1 Rosa/Girrasol EHTF Electrical Heat Traced Flowline 24.9 Jubarte DGC PDG - Pseudo Dry Gas SS Pumps / Compression - Conceptual Dalmation Golfhino Jansz-Lo ESP Electrical Submersible Pump 80 14 King (8) A SS Tieback to Marlin TLP Anadarko US GOM 1,700 5,578 29.0 18.0 496.5 75 50.0 725 1.30 0-95% Aker Solutions 2+1 Spare Twin-Screw ITT Bornemann / Loher Nov-07 15-Feb-09 15.0 4,920 (ft) (LDT) (LDT) 35 SS Pumps / Compression - Awarded and in ETH Electrical Trace Heating 15 Vincent O Dual MPP System Woodside NW Shelf, Australia 475 1,558 3.0 1.9 2,400.0 363 42.0 609 1.80 25-70% OneSubsea 2+2 Spare Helico-Axial OneSubsea Aug-10 1-Mar-19 77.1 1,500 (m) Dalmation Courtesy of Aker Solutions Courtesy of Nexans 21.7 Manufacturing/Delivered Marlim FFD Full Field Development 60 16 Marlim A SBMS-500 SS Field Test Petrobras Campos Basin 1,900 6,234 3.1 1.9 500.0 75 60.0 870 1.20 0-100% Curtiss-Wright 1 Twin-Screw Leistritz King Jack & St. Malo MPP 30 SS Pumps / Compression - Operational Greater Enfield 6,560 (ft) Jack & St. Malo Fig. 3: Aker Solutions DEH Riser Cable Floating Production System FPS 17 Golfinho Field BCSS O Seabed ESP-MOBO, Uses BCSS (14) Petrobras Espirito Santo Basin 1,500 4,922 11.0 6.8 146.0 22 138.0 2,002 1.20 10-40% TechnipFMC (33) 2 ESP Schlumberger (REDA)(33) Dec-14 4-Jan-18 37.0 18.6 2,000 (m) Parque Das Conchas Ph. 1 Fig. 4: TYPE 1B: Pipe-In-Pipe DEH for Two Heated Segments/Flowlines Julia FPSO Floating, Production, Storage & Offloading 40 18 Dual MPP System Murphy Oil Congo, W. Africa 1,338 4,390 3.0 1.9 350.0 53 41.0 595 0.85 28% OneSubsea 2+1 Spare Helico-Axial OneSubsea Sep-10 1-Oct-13 36.5 Parque Das Conchas Ph. 2 Parque Das Conchas Azurite Field A Deepwater FPU Floating Production Unit DGC - Dry Gas Compression 25 8,200 (ft) Julia MPP Repl. Topside Power 19 Golfinho Field Caissons O MOBO BCSS (ESP) Caissons (14) Petrobras Espirito Santo Basin 1,500 4,922 5.0 3.1 146.0 22 138.0 2,002 1.20 10-40% Aker Solutions 2 ESP Schlumberger (REDA)(33) Dec-14 4-Jan-18 36.1 15.5 Otter Supply

20 Depth Feet/ Water GLR Gas Liquid Ratio Jack & St. Malo 2,500 (m) Cascade & Chinook WGC - Wet Gas Compression 20 Espadarte (Field Trial) A Horizontal ESP on Skid Petrobras Brazil 1,350 4,429 11.5 7.1 125.0 19 100.0 1,450 0.90 10-40% TechnipFMC 2 ESP Baker Hughes Dec-11 Mar-13 14.5 DEH Cable 20 Wetmate power GVF Gas Volume Fraction Differential Pressure (Bar) Rosa/Girassol Current in outer 0 21 Parque Das Conchas (BC 10) Phase 1 (20) O Caisson / Artifical Non-Separated Shell Campos Basin 2,150 7,054 9.0 5.6 185.0 28 152 2,205 1.10 40% TechnipFMC 2 ESP Baker Hughes Jul-09 1-Mar-19 115.3 connectors Conventional 12.4 9,840 (ft) Subsea Compression HPHT High Pressure/High Temperature Stones pipe 80 85 90 95 100 22 Parque Das Conchas (BC-10) Phase 2 O 2 additional ESP systems Shell Campos Basin 2,150 7,054 9.0 5.6 185.0 28 152 2,205 1.10 40% TechnipFMC 2 ESP Baker Hughes Oct-13 1-Mar-19 64.4 Ceiba Field(FFD) 3,000 (m) Subsea Pumps HSP Hydraulic Submersible Pump 15 COURTESY OF 23 Parque Das Conchas (BC-10) MPP Repl. O Replacement MPP system Shell Campos Basin 2,150 7,054 9.0 5.6 185.0 28 1.50 70% TechnipFMC 1 Helico-Axial TechnipFMC Dec-18 1-Mar-19 2.5 Current in inner GVF (%) 9.3 11,480 (ft) Outer Pipe HV High Voltage pipe Tieback Distance Tieback Parque Das Conchas Present 24 Jubarte Field - Phase 2 O Tieback to FPSO P-57, Uses BCSS (14) (22) Petrobras Espirito Santo Basin 1,400 4,593 8.0 5.0 1,325.0 200 200 3,000 1.20 30-40% Aker Solutions 15 ESP Schlumberger (REDA) 6-Dec-10 1-Mar-19 98.6 3,500 (m) Insulation IPB Integrated Production Bundle 10 Deepwater Ultra 1990 1995 2000 2005 2010 2015 2020 2025

Fig. 1: Pseudo Dry Gas (PDG) Inline Liquid Removal Unit. 25 Cascade & Chinook I, N Skid BCSS - Horizontal ESP on Skid (6) Petrobras US GOM 2,484 8,150 8.0 5.0 135.0 20 220.0 3,191 1.10 10% TechnipFMC 4+2 Spare ESP Baker Hughes 14-Jul-12 Unkown 6.2 US MMS Definitions: IOR Improved (Increased) Oil Recovery Inner pipe 26 Barracuda O SS MP High Boost Pump System (30) Petrobras Campos Basin 1,040 3,412 10.5 6.5 280.0 42 70.0 1,015 1.50 35-60% OneSubsea 1 Helico-Axial OneSubsea 14-Jul-12 1-Mar-19 79.4 Vigdis kW Kilowatt Conventional

Short 5 COURTESY OF COURTESY OF Year CROSS SECTION 27 Montanazo & Lubina O Single MPP System Repsol Mediterranean 740 2,428 12.3 7.6 80.0 12 65.0 943 0.23 10% OneSubsea 1 + 1 Spare Centrifugal (SPP) OneSubsea 15-Jan-14 1-Mar-19 61.3 3.1 Stones Mid-Line Assembly (MLA) Km Kilometer Conducting Bulkhead Conducting Bulkhead Short MBLPD Thousand Barrels of Liquid Per Day 28 Schiehallion I, N 2 x Dual MPP Systems BP UK, West of Shetland 400 1,312 4.0 2.5 2,700.0 408 26.0 377 1.80 74% GE / OneSubsea 4+0 Spare Helico-Axial OneSubsea Courtesy of Aker Solutions 0 (mi) Courtesy of INTECSEA 29 CLOV (19) O Subsea MPP System Total Angola, Blk 17 1,170 3,839 11.0 6.8 660.0 100 45.0 652 2.30 50% OneSubsea 2+1 Spare Helico-Axial OneSubsea 31-Jul-16 1-Mar-19 30.9 0 (km) MCP Modular Compact Pump 1995 2000 2005 2010 2015 2020 2025 “GAME CHANGING” SUBSEA BOOSTING TECHNOLOGY MPP Multiphase Pump 30 Jack & St. Malo O 3 x Single SPP Systems (JSM) Chevron US GOM 2,134 7,000 21.0 13.0 1,191.0 180 241.3 3,500 3.00 10% OneSubsea 3+2 Spare Centrifugal (SPP) OneSubsea 10-May-16 1-Mar-19 33.6 Present FULL WELLSTREAM SUBSEA BOOSTING MW Mega Watts 31 Lyell Retrofit O MPP Retrofit System - Tieback to Ninian CNR UK North Sea 145 476 7.0 4.3 700.0 106 21.0 305 1.00 97% OneSubsea 1 Helico-Axial OneSubsea 21-Aug-14 1-Mar-19 54.2 Year Fig. 1: Torque Converter Function – Variable Guide Vane Fig. 5: FSubsea Pump Assembly with TYPE 2: Electrical Trace Heating (ETH) - Pipe-in-Pipe Voith Torque Converter OPEX Operational Expenditures Fig. 5: TechnipFMC Electrically Trace Heated Pipe-in-Pipe (ETH-PiP) Fig. 6: Subsea 7/ITP InterPipe Electrically Heat Traced Pipe-in-Pipe 32 Rosa / Girassol (24) O Field Expansion Project Total Angola, Blk 17 1,350 4,429 18.0 11.2 600.0 91 130.0 1,885 2.50 20-50% OneSubsea 4+2 Spare Helico-Axial OneSubsea Q2 2015 1-Mar-19 Torque Converter Function O/W Oil and Water 33 O 2 x Dual MPP Station OKEA Offshore Norway 268 879 4.0 2.5 1,710.0 253 47.5 689 2.30 10-31% OneSubsea 2 Helico-Axial OneSubsea 24-Nov-16 1-Mar-19 27.1 Oil Subsea Tiebacks: (NOTE 1. SEABED & RISER ONLY, NOTE 2. EXCLUDES DOWNHOLE ESPs) 2. NOTE SEABED & RISER ONLY, 1. (NOTE Draugen Field (Infill Program) Passive Insulation Gas Subsea Tiebacks: COURTESY OF Variable Guide Vanes Specific insulation material with reduced Centralizer PCM Power Control Module 34 Julia O SS Tieback with Dual SPP Systems ExxonMobil US GOM 2,287 7,500 27.2 17.0 331 50 175.0 2,550 3.00 10% OneSubsea 2 Centrifugal (SPP) OneSubsea 18-Apr-16 1-Mar-19 34.3 Guide Vanes Flowline pressure in PiP annulus PDG Pseudo Dry Gas 35 Moho Phase 1bis O Brownfield Tieback to Alima FPU Total Congo, W. Africa 650 2,133 6.7 4.0 400 60 133.5 1,935 3.50 49% OneSubsea 2 Helico-Axial OneSubsea 2016 Heating Wires PIP Pipe-in-Pipe 36 Stones O Single Phase HPHT Pump System Shell US GOM 2,927 9,600 5.0 3.1 TBD TBD TBD TBD TBD <10% OneSubsea 2 +1 Spare Centrifugal (SPP) OneSubsea 2018 GRAPH 5: SUBSEA BOOSTING – TOTAL THROUGHPUT vs. DIFFERENTIAL PRESSURE* PWRI Produced Water Reinjection 37 Appomattox C MPP in future Phases Shell US GOM 2,222 7,290 TBD TBD 3,990 275 RWI Raw Water Injection (psi) (bar) 38 Parque Das Baleias O Horizontal ESP on Skid Petrobras Espirito Santo Basin 1,500 4,922 10.0 6.2 125.0 19 140 2,058 1.20 10-25% TechnipFMC 5 +1 Spare ESP Schlumberger (REDA) 3/19/14 1-Mar-19 59.3 Rotary Vane SIT System Integration Test 3,625 250 Jack & St. Malo SS Pumps - Awarded and in Actuator Output Shaft 39 Greater Enfield O Dual MPP System Woodside W. Australia 850 2,788 32.0 20.0 959.0 145 110.0 1,595 2.60 5.20 81% OneSubsea 2+1 Spare Helico-Axial OneSubsea Mid-2019 Carrier Pipe SMUBS Shell Multiphase Underwater Boost Station (SPPs) Manufacturing or Delivered TC-Turbine 40 Dalmatian O Single MPP System SS Tieback to Petronius Murphy E & P Co. US GOM 1,779 5,837 35.0 22.0 231.0 35 150.0 2,176 2.20 2.20 65% OneSubsea (34) 1+1 Spare Helico-Axial OneSubsea (34) Q4-2018 3,265 225 SS Pumps - Operational Trace Heating Cable SPP Single Phase Pump Outer Pipe 41 Otter Field O MPP System SS Tieback to N. Cormorant Platform TAQA Bratani UK North Sea 184 603 22.0 13.7 853.0 129 48.0 696 2.00 2.00 75% OneSubea 1+1 Spare Helico-Axial OneSubsea Q4-2018 Input Shaft Centralizer SRSWI Subsea Raw Seawater Injection 2,900 200 TC-Impeller Housing SS Subsea Fig. 2: Field Architecture Locations of Pseudo Dry Gas (PDG) Inline Liquid Removal Units. 42 Vandumbu Field (36) O Dual MPP Pump Station ENI Angola Block 15/06 1,225 4,019 3.0 1.9 430.0 65 190 2,755 3.20 5.00 70% TechnipFMC 2+1 Spare Helico-Axial TechnipFMC 2-Dec-18 1-Mar-19 2.9 Julia (SPPs) Jubarte Field (Phase 2-ESPs) Protection Sheet Courtesy of TechnipFMC/Heat Trace Ltd SSP Subsea Processing 43 Vigdis M Subsea Boosting of existing wells OØK - Equinor Offshore Norway 292 958 6.5 4.1 1,500.0 50.0 725 3.20 3.20 20-40% OneSubsea 1+1 spare Helico-Axial OneSubsea Q2, 2019 2,540 175 Fiber Optic Cable COURTESY OF Inner pipe SSPU Subsea Separation and Pumping Unit Subsea 44 Who Dat M Subsea Boosting LLOG US GOM - MC 503 943 3,094 5.6 3.5 370.0 25 151.7 2,200 2.20 2.60 50-76% TechnipFMC 1 Helico-Axial TechnipFMC Sep-19 2,175 150 SUBSIS Subsea Separation and Injection System Manifold 45 Jack & St. Malo MPP M MPP for Stage IV Chevron US GOM 2,134 7,000 21.0 13.0 207.0 3,000 3.80 OneSubsea 3+2 Spare Helico-Axial OneSubsea 2020 Courtesy of Subsea 7/ITP InterPipe Rosa/Girrassol (MPPs) Courtesy of Voith Fig. 8 TLP Tension Leg Platform M1 46 Lufeng 22/1 Fields (37) C Subsea Boosting CNOOC Ltd. China, Lufeng Fields 1,815 125 1 HowHowit‘s doneit‘s done! ! How it‘s done! Figs. 7 & 8: Saipem Electrically Heated Pipe-in-Pipe - for TSP Twin Screw Pump Greater Enfield 1 A SUBSIS (SS Sep. and WI Sys.) Equinor Offshore Norway 340 1,116 3.5 2.2 250.0 38 151.0 2,190 1.60 0% GE / OneSubsea 1+1 Spare Centrifugal (SPP) OneSubsea Aug-01 1-Mar-19 209.7 A Liquid Troll C Pilot (15) ConventionalVARIABLEConventionalSubsea FREQUENCY/SPEEDSubseaVariableVariable Speed Speed Pump Pump Drive DRIVE DriveVoith CONFIGUATIONS Subsea Variable Speed Pump Drive TYPE 3: Flexibles with active heating J-lay/S-lay installation; employs a sliding configuration TRL Technology Readiness Level 1,450 100 Removal Unit Gas Flowline 2 Columba E. I, N Dual SPP System CNR Northern North Sea 145 476 7.0 4.3 331.0 50 305.0 4,424 2.30 0% OneSubsea 2+0 Spare Centrifugal (SPP) OneSubsea May-07 1-Oct-13 76.4 Fig. 9: TechnipFMC Integrated Production Bundle VASPS Vertical Annular Separation and Pumping 3 Tyrihans A 3 SPP & SS RWI Filtration System Equinor Offshore Norway 270 886 31.0 19.3 583.0 88 205.0 2,973 2.70 0% FMC/Aker Solutions 2+1 Spare Centrifugal (SPP) Aker Solutions 12-Mar-13 1-Mar-19 71.5 1,090 75 VFD (IPB) - Electrically Heat Traced Flexible System SS Tree (XT) Differential Pressure 2 3 4 WATER Vincent M2 Gas SUBSEA 4 Albacora L'Este Field (31) O Raw Water Injection to 7 Wells Petrobras Campos Basin, Brazil 400 1,312 4 to 9 2.5-6.0 1125 170 85 1,233 1.2 0% OneSubsea 3+1 Spare Centrifugal (SPP) OneSubsea 14-Mar-14 1-Mar-19 59.4 Draugen (MPPs) VSD Variable Speed Drive INJECTION (MPPs) Treatment 5 Ekofisk Seabox Pilot (R&D) (39) O Subsea Water Treatment, lifted topside for injection ConocoPhillips Offshore Norway 78 256 0.0 0.0 267 40 250 3,626 0% ConocoPhillips / NOV 1 Centrifugal (SPP) Halliburton 1-Oct-18 1-Sep-19 11.0 725 50 Ceiba Field WD Water Depth B C D (FFD) (MPPs) Facility 1 Zakum A Shallow Water Test Separation System BP Offshore Abu Dhabi 24 79 1969 1972 36 WGC Wet Gas Compression P1 360 25 Courtesy of FSubsea AS Liquid Pipeline 2 A SS Separator/Slug Catcher Repsol Sinopec (27) UK North Sea 420 1,378 Core of the IPB WI Water Injection Booster Pump Highlander Field (32) 3 Argyll A SS Sep. and Pumping Unit (SSPU) Hamilton Bros UK North Sea 80 262 BOET (See Table 3 Def.) 1989 0 0 M XFMR Transformer Tie-in point M 4 Marimba Field I, N VASPS Field Test (21) Petrobras Campos Basin 395 1,296 1.7 1.1 60.0 9 52.0 754 0.3 OneSubsea 1 ESP Schlumberger (REDA) Jul-01 1-Jul-08 83.0 (MBLPD) 0 50 100 150 200 250 300 350 400 450 M (m³/hr) 0 330 660 995 1,325 1,655 1,990 2,320 2,650 2,980 Electrical heat 5 Troll C Pilot (15) A Horizontal SUBSIS (SS Sep. & WI Sys.) (23) Equinor Offshore Norway 340 1,116 3.5 2.2 250.0 38 151.0 2,190 1.60 0% GE / OneSubsea 1+1 Spare n/a OneSubsea Aug-01 1-Mar-19 209.7 seafloor seafloor VFD Note: Booster pump (P1) and single phase mini-pumps within each Liquid Removal Unit are proposed to be FSubsea Pumps with integrated Figures 2, 3, and 4 Courtesy of Voith trace cables Voith Torque Converter. See Green Section titled: “Game Changing Subsea Boosting Technology”. 6 Tordis (13) O Separation, MPP Equinor Offshore Norway 210 689 11.0 6.8 1,500.0 227 27.0 392 2.30 10-68% TechnipFMC 1+1 Spare Helico-Axial OneSubsea Oct-07 1-Mar-19 136.2 *(As of Feb., 2019) Throughput Fig. 2: Config. 1 Fig. 3: Config. 2 Fig. 4: Config. 3 – Variable Speed Pump Drive is incorporated Information Accuracy: We have attempted to use 7 Parque Das Conchas (BC 10) Phase 1 O Separation Caisson / Artifical Lift Manifold Shell Campos Basin 2,150 7,054 25.0 15.6 185.0 28 152.0 2,205 1.10 15% TechnipFMC 4 ESP Baker Hughes Centrilift Aug-09 1-Mar-19 114.3 COURTESY OF Gas lift tubes correct and current, as of press time, information for the Fig. 3: Pseudo Dry Gas (PDG) Process Flow Diagram VFD on Topsides VFD on Seafloor with the pump assembly which sits on the Seafloor 8 O Caisson Separation and Boosting (29) Shell US GOM 2,438 7,999 0.0 0.0 132-264 20 - 40 158.8 2,303 1.20 15% TechnipFMC 5 ESP Baker Hughes Centrilift Mar-10 1-Mar-19 84.0 subsea processing systems and equipment described Perdido Thermal insulation herein. No installed, sanctioned, or pending application 9 Pazflor O 3 Gas/Liquid Vertical Separation System Total Angola, Blk 17 800 2,625 4.0 2.5 1,800.0 272 105.0 1,523 2.30 <16% TechnipFMC 6+2 Spare Hybrid H-A OneSubsea Aug-11 1-Mar-19 89.8 Courtesy of Saipem was intentionally excluded. We have summarized the Production Umbilical Fig. 3: Teledyne interconnect system: umbilical Fig. 4: Teledyne 10kV, 250A SUBSEA SEPARATION 10 Marlim SSAO - Pilot O In-Line Separation Petrobras Campos Basin 878 2,881 3.8 2.4 135.0 20 245 3,553 1.9 67% TechnipFMC 1 Centrifugal (SPP) OneSubsea Mar-13 1-Mar-19 70.9 SUBSEA POWER CONNECTORS SUBSEA POWER DISTRIBUTION capability and operating experience by acting as a neutral Multiphase terminations, HV wetmate flying leads, and Electrical Wetmate EFL, Courtesy of TechnipFMC Courtesy of Saipem Liquid Removal XT XT 11 Parque Das Conchas (BC 10) Phase 2 M 2 additional ESP systems Shell Campos Basin 2,150 7,054 25.0 15.6 185.0 28 152.0 2,205 1.10 15% TechnipFMC 2 ESP Baker Hughes Centrilift party and integrator of information. Information has Flowline tubing hanger connections to power ESP’s for Subsea Boosting and EQUIPMENT Gas Unit Inline Skid 12 Congro & Corvina (26) CP VASPS w/Horizontal ESP Petrobras Campos Basin 280 919 8.0 5.0 135.0 20 21 305 0.4 <10% TechnipFMC 1 ESP Baker Hughes Centrilift Fig. 1: GE MECON DM 145/700 Dry-Mate Fig. 2: Siemens ElecTRON - Subsea Instru- been collected from public sources, company brochures, Gas Flowline Processing personal interviews, phone interviews, press releases, Treatment SS Manifold SUTA connectors mentation Feedthrough Connector System CURRENT STATUS CATEGORIES NOTES: 1. Qualification Status Warning - The qualification status information shown in this achieved 50,000 operating hours with nearly 100% availability as of Dec. 2018. holes in the seabed, 200m from producing wells. MOBO - Modulo de Bombas and Argonauta B-West. Argonauta O-North to be added in Phase 2. Awarded to FMC 26. Congro & Corvina SS Separation/Boosting Project - This project has been canceled. January 2015. 1 of each still has a Baker Hughes ESP as of February 2015. TYPE 4: Production Flow Continuous Heating TYPE 5: Hot Water industry magazines, vendor-supplied information, and Facility table, and throughout the poster, are based on unverified claims from equipment 8. King Field MPP are off line. There are no indications that Anadarko will reactivate (Pumping Module). but installed by Subsea 7. Petrobras has determined commercially of the fields is not feasible. 34. Dalmatian will be the longest subsea tieback in the GOM with SS boosting (35 KMs / Fig. 1: 200 Km 30 MVA Power Station with 145kV Step-down trafoan switch- Heated web sites. No guarantee is made that information is XT XT C Conceptual Project (Per Public Domain) suppliers and field operators. These qualification status designations are not these pumps in the near future. 15. Troll C Pilot: Abandoned and not in operation. Separation began on Aug. 25, 2001. 21. Marimba VASPS - 2000 - First installation in Marimba (JIP Petrobras / Eni-Agip/ 27. Repsol Sinopec - full Operator name is REPSOL SINOPEC RESOURCES UK LIMITED. 22 Miles). Murphy E & P has awarded the Subsea Integration Alliance (SIA) (OneSubsea gear-less subsea VSDs for up to 2x 12.5 MW Compressors Power Station with Fig. 10: Saipem Local Heating Station – Retrievable accurate or all-inclusive. Neither INTECSEA nor Offshore necessarily derived using technology readiness level (TRL) assessments per API RP 9. Nuovo Pignone SpA is a subsidiary of GE (General Electric). See 2010 OTC paper 20619, page 10 for Operational experience. ExxonMobil, 2001 - Startup and Operation (July to Dec.) until ESP failure, 2002 End of Repsol acquired the field through the Talisman acquisition. + Subsea 7) an EPCIC contract for the subsea multi-phase boosting system. Mini Pump Q Qualified/Testing 17Q, DNV-RP-A203, or ABS Guidance Notes on Qualifying New Technologies. 10. Gullfaks - 2016 OTC Paper 27224 by OneSubsea provides an overview of the 16. Mutineer/Exeter Projects: Manufacturers are: OneSubsea and Centrilift. There are 2 JIP, By-pass production, 2003 - Workover Plan (IWP), 2004 - Workover and Re-start 28. Ormen Lange Gas Compression 2 - Currently Norske Shell is working to simplify the transformer, switchgear & VSDs for pumps and compressors up to 12.5MW Fig. 11: Subsea 7 Pipeline Bundle Magazine guarantees or assumes any responsibility Power <45 kW 35. Peon Development - Statoil and partners placed the project on hold. Symbol Key M Awarded and in Manufacturing or Delivered 2. Pumping & Boosting: The terms “Pumping” and “Boosting” are used interchangeably Technology Qualification Program (TQP) completed for Statoil’s Gullfaks Subsea ESPs per well feeding 1 x OneSubsea MPP per asset on seafloor. on May 8, 2004. From 2005 until 2008 VASPS operated well until well failure. design, remove unnecessary redundancy, module size, and weights by more than 50%. 36. System Flow Rates - Gas flow rates not reported for Boosting or Separation. with multiple flowlines, controls, or liability for any party’s (See Note 1.) throughout this poster and in the industry. Compression (GSC) project. 17. Draugen MPP - This was the world's first Multiphase Subsea Pump which was 22. Jubarte Field (Phase 2) - Phased installations from 2010 through 2015. Wells were 29. Peridido - Cassion for separation is 350 feet long drilled into the seabed. Read 2011 37. Lufeng Fields - Conceptual study for boosting on Lufeng Fields consist of: Lufeng & active heating inside a carrier use of the information Liquid Flowline Pump O Installed & Currently Operating 3. Unit Motor Power: Is the unit motor power for either a pump or compressor assembly. 11. Åsgard Project: See 2016 OTC Paper # 27197 by Anders Storstenvik of Aker installed in 1993. It ran successfully from 1995 for 12 Months (1,000 hours) and was connected to the FPSO P-57. All wells will have gas-lift as a backup. OTC paper 21716. POSTER 4. Differential Pressure values are for individual boosting units. Solutions. decommissioned and abandoned due to change in water injection strategy. 23. SUBSIS - The world's longest operating subsea separation system and first subsea 30. Barracuda - is the first installation of the high boost MPP. See 2013 OTC paper 22-1, Lufeng 14-4/14-8/8-1, Lufeng 15-1. The study is being done by Aker Kvaerner pipe (heating using e.g. inhibited presented. If any information Liquid Removal Unit I,N Installed & Not Currently Operating or In-Active 5. GVF = Gas Volume Fraction at inlet of a boosting assembly. 12. START: Month & Year indicates first month and year of operation for the SS 18. Equinor (formerly Statoil) - See 2016 OTC Paper 27201 by by Rune Ramberg & water injection pump system. Abandoned and not in operation. 24217 for addition infomation about the MPP. for CNOOC Ltd. Booster Pump 38. UK Oil and Gas Technology Centre (OGTC) funded study with multiple operators and potable water, reinjected is found to be incorrect, not XT Subsea Tree A Abandoned, Removed 6. Cascade & Chinook - Utilizes horizontal ESPs on a skid above mudline. It is an processing system. other for Statoil’s research leading up to the Subsea Factory Compressor Stations. It 24. Rosa/Girassol development project includes the Rosa field with 4 SS boosting 31. Albacora Field - Reference 2013 OTC paper 24167. current, or has been omitted, Power <300 kW alternative ESP boosting configuration to caisson in the seabed. This technology is 13. Tordis Field: SS Separation, 1+1 Spare Multiphase Boosting Pumps for production, highlights Statoil’s future vision. pumps. 1st set operational in Sept., 2015 & 2nd set operational in April, 2016. 32. Highlander Field - SS Tieback to the Tartan Field which has a SS separator/slug Oil and Gas Authority (OGA) for known basin with significant number of small to medium produced water) CP Canceled Project designed to cover the low GVF and high DeltaP multiphase flow. Single phase pumps for produced water from subsea separator transported to 19. CLOV - Two (2) MPPs are on the sea floor since Dec. 2015. The seabed MP boosting 25. Gullfaks South Brent - was shut down in Nov. 2015. The root cause has been identified catcher installed for the tie-in to the Tartan Platform. See papers: 1994 OTC #7438- stranded fields over large geographical area. please send comments to Note 1: The liquid (condensate) flowline could be part of the umbilical if project specifics allow. COURTESY OF 7. Åsgard is the longest subsea tieback in the world with SS gas compression. MAN Gullfaks C for further processing. pumps will boost flow from 4 fields which are: Cravo, Lirio, Orquidea and Violeta. as “AC corrosion in the umbilicals that led to the leakage, ruling out any fault with the MS, 1987 SPE #13970-PA, 1987 SPE #16532-MS 39. Ekofisk Pilot - Seabox subsea water treatment. Water lifted topside for injection into [email protected]. P/H Postponed or On Hold Energy Solutions’ first subsea compression trains at Equinor’s Åsgard field have 14. BCSS - Centrifugal Subsea Submersible Pumps: Pumps are placed in protective 20. Parque Das Conchas (BC 10) Phase 1 - Composed of 3 reservoirs: Ostra, Abalone compressors” according to a Statoil spokesman. Gas compressors started in Aug., 2017. 33. Petrobras changed ESP supplier from Baker Hughes to Schlumberger (REDA) dry well. Reference 2019 OTC paper 29552. Courtesy of Saipem Courtesy of Subsea 7 134 ©2019 Offshore Courtesy of BHGE, a GE company Fig. 2: Siemens Conceptual Courtesy of Siemens Courtesy of Teledyne Subsea Power Grid* Fig. 3: SS Compression Station 2.0 concept Fig. 6: Åsgard Compressor NOTES: Fig. 3: Siemens SS Transformer Fig. 4: Siemens Conceptual Fig. 5: Siemens Conceptual Fig. 6: GE 24kV Switchgear SUBSEA GAS COMPRESSION SYSTEMS Fig. 5: Åsgard Subsea Compression Module CHART 1 – SUBSEA SUPPLIER MATRIX (As of Feb., 2019) SUBSEA PROCESSING compared to Åsgard SS Compression module before starting 1. Aker Solutions and MAN Diesel & Turbo have formed an Courtesy of Aker Solutions & ABB Alliance for SS Variable Speed Drive* Prototype Tested in Shallow Water alliance for the next generation of subsea compression Power & Automation Prototype at Shallow Water Test* SS Switchgear* installation Fig. 1: Ormen Lange Compression Station Test Fig. 2: TechnipFMC Conceptual 2-Train Dry Gas systems. Fig. 5: Siemens DigiTRON+ and Fig. 6: Siemens SpecTRON 45 - 45kV wet mate Fig. 4 SUBSEA SEAWATER SUBSEA SUBSEA PARTNERSHIPS / OTHER 2. Subsea seawater injection refers to only those projects Compression Station with Replaceable Modules SUBSEA SUBSEA GAS HV & CONTROL TESTING TREATMENT & SEPARATION ACTIVE ALLIANCES / SUPPORTING utilizing a subsea pump to inject seawater and does DigiTRON3 - 1kV and 3kV wet connectors for subsea power distribution Fig. 5 BOOSTING COMPRESSION AC/DC POWER SYSTEMS FACILITIES Fig. 7: Åsgard 19 MVA Fig. 3 INJECTION (2) SYSTEMS HEATING (11) COLLABORATIONS SYSTEMS not include typical water injection using a pump on a mate controls connectors topside facility. Courtesy of Teledyne Subsea Transformer Module 3. Liestritz have partnered with Rosetti Marino for potential twin screw marinization. PUMP ELECTRIC POWER ASDS/VSDS, HV AKER SOLUTIONS AKER SOLUTIONS AKER SOLUTIONS PUMP SUBSEA TORQUE AKER SOLUTIONS AKER SOLUTIONS (1) COMPRESSION ABB Aker Solutions/ UMBILICALS PENETRATORS akersolutions.com akersolutions.com akersolutions.com 4. Deutsch is part of TE Connectivity. SYSTEM MOTOR COMPRESSORS ABB Alliance (14) CABLES X-FORMERS CONNECTORS Fig. 7: GE MECON WM 36/500 MANUFACTURERS CONVERTER akersolutions.com akersolutions.com SYSTEM abb.com PACKAGERS MANUFACTURERS akersolutions.com & SWITCHGEAR 5. TechnipFMC and Sulzer have formed a long-term and abb.com exclusive collaboration agreement. Wet-mate connectors BAKER HUGHES ALPHA THAMES BAKER HUGHES a GE company 6. PROLAB is a Sulzer company. AKER SOLUTIONS AKER SOLUTIONS AKER SOLUTIONS VOITH (17) BAKER HUGHES BAKER HUGHES AKER SOLUTIONS (1) AKER SOLUTIONS ABB AKER SOLUTIONS AKER SOLUTIONS ABB (14) ALSTOM BENESTAD (7) a GE company alpha-thames.co.uk Courtesy of Aker Solutions a GE company a GE company Aker Solutions/ geoilandgas.com geoilandgas.com 7. Benestad is an Aker Solutions company. akersolutions.com akersolutions.com akersolutions.com voith.com geoilandgas.com geoilandgas.com akersolutions.com akersolutions.com MAN Diesel & Turbo Alliance abb.com akersolutions.com akersolutions.com abb.com alstom.com benestad.com akersolutions.com 8. Diamould is a OneSubsea company. Courtesy of Siemens Courtesy of Siemens Courtesy of Siemens Courtesy of Siemens mandieselturbo.com TechnipFMC BAKER HUGHES FLOWSERVE 9. ASCOM re-branded as Sulzer Chemtech. Fig. 4: NOV Passive Cooler – Field proven a GE company BAKER HUGHES BAKER HUGHES Curtiss-Wright ONESUBSEA (12) ONESUBSEA BAKER HUGHES HEAT TRACE LTD. ALCATEL BICC BERCA CORTLAND AKER SOLUTIONS (14) DEUTSCH (4) DEUTSCH (4) fmctechnologies.com flowserve.com a GE company a GE company a GE company Aker Solutions/ geoilandgas.com 10. FSubsea (Fuglesangs Subsea AS) and the German pump technology lowering production temperature curtisswright.com onesubsea.com onesubsea.com heat-trace.com alcatel-lucent.com biccberca.com cortlandandcompany.com akersolutions.com te.com te.com Courtesy of GE Courtesy of Aker Solutions geoilandgas.com geoilandgas.com geoilandgas.com Saipem Alliance company RuhRPumpen collaborate to develop advanced *The Siemens Subsea Power Grid is shown in Fig. 2, with the main building blocks in Figs. 3, 4, & 5, along with wet-mate 36kV connectors and control system. (complimentary to compression) akersolutions.com subsea centrifugal pump solutions as Fuglesangs Subsea. saipem.com ONESUBSEA (12) SMARTMOTOR TechnipFMC Courtesy of Siemens Courtesy of Aker Solutions Fig. 11: BlueC ONESUBSEA ClydeUnion (SPX FLOW) FLOWSERVE SAIPEM SAIPEM ONESUBSEA (12) NEXANS BRUGG FURUKAWA DRAKA BAKER HUGHES DIAMOULD (8) DIAMOULD (8) onesubsea.com smartmotor.no fmctechnologies.com 11. Includes system integrators and specialty hardware Fig. 10: BHGE Conceptual Courtesy of Statoil a GE company onesubsea.com spxflow.com flowserve.com saipem.com saipem.com onesubsea.com nexans.com bruggcables.com furukawa.co.jp draka.com diamould.com diamould.com suppliers. Fig 14: 200 MW Subsea Courtesy of TechnipFMC Wet Gas Compression Compressor FSubsea/Voith geoilandgas.com Fig.13: Subsea Collaboration (17) 12. Subsea Integration Alliance (SIA) is a worldwide Fig. 9: ABB Conceptual Subsea Fig. 10: ABB 19MVA Power Manager Power Hub with 145kV System (12.5 MW ) fsubsea.com SCHNEIDER ELECTRIC ITT BORNEMANN ITT BORNEMANN non-incorporated partnership between OneSubsea, Courtesy of Siemens Courtesy of BHGE, a GE company Fig. 7: OneSubsea Multiphase Compressor Fig. 8: Subsea HOFIM™ Compressor by MAN Saipem & Curtiss-Wright (18) FLOWSERVE BAKER HUGHES SAIPEM/VEOLIA (16) Sulzer Chemtech (9) TechnipFMC SAIPEM voith.com HITACHI JDR JDR ONESUBSEA (12) BAKER HUGHES BAKER HUGHES schneider-electric.com bornemann.com bornemann.com Power Grid Subsea Transformer Output to Shore from 4 saipem.com a GE company saipem.com a GE company a GE company Schlumberger, and Subsea 7. Fig. 12: Pseudo Dry Gas (PDG) unit flowserve.com sulzer.com fmctechnologies.com saipem.com hitachi.com jdrcables.com jdrcables.com onesubsea.com Fig. 8: Åsgard 100 KVA Subsea Units for GullfaksField Diesel & Turbo for Åsgard curtiss-wright.com bakerhughes.com veolia.com Liestritz/Rosetti Marino geoilandgas.com geoilandgas.com 13. Loher is a Siemens company. Offshore Arrays with 20 x 10 (non-compression) reduces back Partnership (3) SIEMENS LEISTRITZ ONESUBSEA (12) 14. Aker Solutions and ABB have formed an Alliance for Fig. 9: Siemens DigiTRONf - High Control Power Distribution Module ABB Subsea MW Wind Turbines liestritz.com Fig. 8: Siemens SpecTRON 10 - 10kV wet mate transformer Fig.11: ABB Conceptual Subsea Fig.12: ABB Conceptual Subsea pressure approx. 60-120 bar; TechnipFMC FSUBSEA (10, 15, 17) HAYWARD TYLER SEABOX AS TechnipFMC DRESSERXXXXXXXXX RAND SIEMENS MITSUBISHI NEXANS MFX DO BRASIL SCHNEIDER ELECTRIC SEACONXXXXX SIEMENS energy.siemens.com leistritzcorp.com onesubsea.com Power and Automation. optical performance wet mate ABB conceptual fmctechnologies.com fsubsea.com haywardtyler.com nov.com/seabox fmctechnologies.com dresser-rand.comXXXXXXXXX siemens.com mitsubishielectric.com nexans.com mfx.com.br schneider-electric.com seaconworldwide.com energy.siemens.com Fig. 10: Teledyne 5kV, 200A Fig. 11: Teledyne 3kV, 30A Electrical requires 1MW for 1 BScfdsystem Saipem/Curtiss-Wright Corp. 15. FSubsea won the 2017 OTC Spotlight on New Technology connectors for subsea pumping systems variable speed drive Medium Voltage Switchgear Variable Speed Drive Courtesy of NOV Cooperation Agreement (18) Award for their OMNIRISE MINIBOOSTER subsea connector saipem.com PETROBRAS ATALAIA PROLAB (6) Electrical Feedthrough and API- Wetmate Connector BAKER HUGHES SUBSEA 7 / INTERPIPE ITT BORNEMANN LEISTRITZ (3) LOHER (13) TechnipFMC TWISTER BV curtiswright.com NKT NSW NEXANS SIEMENS SIEMENS TELEDYNE D.G.O’BRIEN LAB (Brazil) prolabnl.com processing pump. a GE company subsea7.com 6FB Flame-Proof Penetrator energy.siemens.com 16. Saipem worked in cooperation with Veolia to develop Fig.9: Installation of the OneSubsea bornemann.com leistritzcorp.com automation.siemens.com fmctechnologies.com twisterbv.com geoilandgas.com itp-interpipe.com nktcables.com nsw.com nexans.com energy.siemens.com dgo.com Saipem/Veolia Alliance (16) SPRINGS® Subsea Seawater Treatment system. The Multiphase Compressor Station for Gulfaks saipem.com SHELL GASMER STATOIL: P-LAB & K-LAB veoliawatertechnologies.com system is a subsea technology for the treatment of sea- ONESUBSEA (12) SCHLUMBERGER ONESUBSEA (12) TechnipFMC / Sulzer (5) MAN Energy Solutions (1) TechnipFMC OKONITE PARKER OCEANEERING SIEMENS TELEDYNE ODI TELEDYNE ODI (Houston, TX) (Norway) water utilizing sulphate removal membranes (SR) for the onesubsea.com slb.com onesubsea.com fmctechnologies.com mandieselturbo.com fmctechnologies.com okonite.com parker.com oceaneering.com energy.siemens.com odi.com odi.com SUBSEA INTEGRATION removal of sulphates prior to injection into the reservoir. ALLIANCE (12) SOUTHWEST RESEARCH 17. Voith and Funglesangs Subsea AS (FSubsea) signed a ONESUBSEA, SUBSEA 7, SULZER (5) TechnipFMC / INSTITUTE TechnipFMC / SULZER (5) ONESUBSEA (12) SCHLUMBERGER PRYSMIAN SCHLUMBERGER REDA PARKER TECHNIP UMBILICAL sulzer.com collaborative agreement in May 2016 to develop DIRECT DRIVE SYSTEMS swri.org fmctechnologies.com onesubsea.com subseaintegration fmctechnologies.com prysmiangroup.com slb.com parker.com technip.com hydrodynamic variable speed drives for advanced subsea ABB conceptual medium alliance.com pump applications. voltage switchgear Courtesy of ABB 18. Saipem and Curtiss-Wright Corporation have an exclusive SIEMENS INDUSTRIAL TechnipFMC/Sulzer SUMITOMO PRYSMIAN UMBILICALS INTERNATIONAL TURBO MACHINERY Collaboration Agreement (5) Courtesy of Siemens/ Courtesy of Aker Solutions & ABB global-sei.com prysmiangroup.com umbilicals.com cooperation agreement for the development of pumps for Courtesy of OneSubsea Courtesy of MAN Diesel & Turbo Courtesy of OneSubsea Courtesy of BHGE, a GE company Courtesy of GE Courtesy of INTECSEA COURTESY OF turbomachinerysolutions.com fmctechnologies.com water treatment and injection applications. Courtesy of Siemens Courtesy of Siemens Courtesy of Teledyne Courtesy of Teledyne Figs. 7 & 8 Courtesy of Aker Solutions Courtesy of ABB Courtesy of ABB Courtesy of ABB Saipem Alliance for Power & Automation

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auto-functions for positioning and flying. Last year the ROV completed a 12-week test program at the company’s test tank in Kirkbymoorside, Yorkshire. Sea trials are expected to start in 1Q 2019. A control electronics pod fitted to all XLe observation class vehicles, the company claims, enables superior connectivity and expansion capabilities. Ethernet interfacing allows for seamless integration with other industry sensors using common IP architecture and ease of remote data transfer. Oceaneering has produced the E-ROV, a self-contained, battery-powered ROV system. Comprising an electric ROV, 4G connection buoy, and subsea cage, the system can operate for extended peri- ods of time without being recovered to the surface, which reduces cost and risk. A standard Mako ROV measures 33 in. x 25 in. x 27 in. and weighs about 160 lb. Subsea 7 subsidiary i-Tech Services (Courtesy SEAMOR Marine Ltd.) has extended its underwater inspection and maintenance service to include new the vehicle arms, and adding another degree of freedom to the vehicle head mechanism. mini ROVs for performing smaller scopes SEAMOR Marine Ltd. has unveiled Mako, a heavy payload ROV named after a of subsea work. These are said to be quick shark. The Mako ROV can carry 14 kg (30 lb) as a standard build and is upgradeable to to deploy and easily transported to the 22.5 kg (50 lb). This higher carrying capacity permits larger instrumentation (such as offshore location by helicopter or air- multi-beam imaging sonars) to be integrated. The new ROV can fly at 2 knots thanks craft. The mini ROVs are said to offer to eight thrusters. Four vertical thrusters and four horizontal thrusters provide sta- high maneuverability and a power-to- bility and maximized forward thrust. It also features a large accessory bay with an weight ratio that allows them to carry open, modular design. This design choice, the company said, provides ample space small tools and manipulators that can to mount and position accessories. The ROV has plenty of power to operate multiple be operated in strong currents. They can accessories at once. A standard Mako measures 840 mm x 635 mm x 674 mm (33 in. also be mobilized rapidly and manually x 25 in. x 27 in.) and weighs approximately 72 kg (160 lb). from any platform, FPSO, barge or vessel Forum Energy Technologies has developed a range of electric ROVs. The XLe, of opportunity. designed and manufactured at the company’s Kirkbymoorside complex in northern England, is the first and smallest of the new range. However, it is sufficiently powerful to undertake subsea maintenance and repairs using its optional electric or hydraulic five-function manipulator arm. According to the company, the vehicle’s self-regulating power feature compensates for tether losses, ensuring a constant and stable power delivery to the vehicle regardless of the length of the tether. It employs the same Forum Integrated Control Engine (ICE++) that is featured in the company’s larger work-class and trencher vehicles. This is said to provide a range of auto-pilot and pilot assist modes when appropriate sensors are fitted. Its latest electric ROV is the XLe Spirit. This is the first observation-class ROV to use Forum’s integrated control engine to bring greater functionality commonly only found in larger work- class vehicles. The ROV is said to incorporate several features to maximize its stability for use as a sensor platform, including regulated propulsion power, optimized thruster orientation and Sea trials of the XLe Spirit eROV are expected to start in 1Q 2019. location, accurate thruster speed control and a wide range of (Courtesy Forum Energy Technologies)

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Saudi Aramco has inaugurated a torpedo-shaped AUV. The PB3 PowerBuoy, coupled with Saab’s technologies, creates the AUV is designed to perform surveys to identify seabed clear- premier unmanned system, providing remote charging capa- ance and potential debris around offshore platforms. It can also bilities for both autonomous and remotely operated vehicles. conduct offshore pipeline inspections to determine subsea asset We believe the combined OPT and Saab system can revolu- integrity and locate potential leaks. According to Aramco, the tionize offshore subsea operations by allowing the vehicles to vehicle, which cost $2.5 million to construct, can handle duties recharge on the seafloor and thus remain in the water longer formerly undertaken by a $50-million, large survey vessel. and reduce the reliance on support from manned vessels. The In addition, the AUV’s modular design allows for interchange- unmanned system can increase the range of the vehicle, increase able modifications based on the mission’s needs. For example, operational weather windows for the operators, while improv- the sidescan sonar/bathymetric module for geophysical opera- ing safety for the crew.” tions can serve as a camera for subsea inspection projects, and In addition, Saab Seaeye said that its iCON-based hybrid as the environmental module for oil leak detection surveys. AUV/ROV Sabertooth fitted with a Blue Logic charger is the An additional battery module can be added to the assembly, world’s first system capable of remote docking operations. allowing the AUV to extend the length of its mission. According to the company, the 3,000-m (9,842-ft) rated Saber- Aramco claims the AUV resembles a shrunken vessel, tooth can be based at a remote location docking station ready operable remotely from shore to be launched on pre-programmed or man-controlled missions, or from a boat including inspection, repair and maintenance, research controlling the tasks, and environmental monitor- vehicle through ing. At the docking station, Wi-Fi when tooling packages are within reach of its stored, batteries connection limit. recharged, and When at the required data trans- depth, the vehicle trav- ferred via sat- els along its mission’s route ellite or cable by means of its Inertial Navi- to shore. gation System. Sonardyne

RESEARCH AND Sabertooth fitted with a Blue Logic DEVELOPMENT inductive device is said to be the Collaboration is playing a key role in help- world’s first system capable of remote ing the industry develop technologies and docking operations. (Courtesy Saab Seaeye) solutions to increase autonomy and remote residency of the subsea systems. Shell has awarded Saipem a license to develop International Ltd. has started a collaborative project to improve technology for FlatFish, a resident subsea auton- the autonomy for long-endurance AUVs. With partners L3 ASV omous vehicle designed to perform subsea asset inspections. and the National Oceanography Centre (NOC), the company This should be qualified for commercial application by 2020. will focus on longer-term navigational accuracy for AUVs in FlatFish is a Brazilian project previously developed over a deepwater, while reducing power requirements and increasing four-year period by SENAI CIMATEC in partnership with DFKI, autonomy in marine operations. with funding from the ANP R&D program and EMBRAPII. The Innovate UK-supported Precise Positioning for Per- Saipem plans to add capabilities for riser inspection, data sistent AUVs (P3AUV) project will involve trials using Sonar- harvesting from subsea sensors, contactless monitoring of dyne’s underwater positioning technology on the NOC’s Autosub cathodic protection systems, and a ‘flying-hanging garage’ for Long Range (ALR) and L3 ASV’s C-Worker 7 autonomous sur- launch/recovery and subsea recharging/reprogramming of the face vehicle (ASV). The project is due to run until late 2019. FlatFish from offshore platforms. These enhancements will be P3AUV will focus on three key areas. One is to increase supported by SENAI CIMATEC which, along with Saipem do long-duration navigational accuracy by integrating low- and Brasil, entered the development arrangement with Shell Bra- high-power inertial navigation system (INS) sensors. The sec- sil last December. ond area is to improve positioning accuracy while underwa- Ocean Power Technologies Inc. (OPT) and Saab Seaeye Ltd. ter vehicles descend and ascend through the water column, have signed a non-exclusive agreement to pursue mutual oppor- through the integration of doppler velocity log current mea- tunities through joint system solution development and mar- surement capabilities and INS technologies with onboard data keting. The agreement anticipates a preliminary focus on AUV processing. The third area is to enable ASV deployment of sea- and ROV charging and communications systems. floor positioning transponders. • OPT President and CEO George Kirby said: “We believe OPT’s

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The subsea gas compression technology on the Åsgard field is expected to increase the reservoir’s productive life by 15 years. (Photo by Elin A./Courtesy Equinor)

Technology gains taking subsea processing deeper, farther out Industry advances helping meet field development challenges

JOHN MORGAN, REBECCA ROTH, LEE THOMAS, MATAI WILSON AND TERRY WOOD, INTECSEA

SINCE THE RELEASE of the first Worldwide Survey of Subsea ALLIANCES, PARTNERSHIPS, AND JIPS Processing Technology poster in Offshore in 2008, INTECSEA has Because of the costly nature of bringing the technology to mar- monitored the status of the technologies and systems used on the ket, various alliances and partnerships have emerged (captured seafloor to enhance reservoir recovery rates. The technologies con- on the poster in Chart 1 – Subsea Supplier Matrix). Partnerships tinue to mature with each successful field development application. or collaborations can bring technologies which, when combined, However, it is a long and costly process to bring the technology to result in even greater benefits. Additionally, collaborative efforts market. And sometimes the process takes longer to find the right greatly reduce the costs associated with maturing the technology match of the technology for a field development application. The through to each TRL (Technical Readiness Level). greatest challenge for operators is the risk of using a new technol- An assessment of the history of subsea processing reveals, that ogy or a combination of technologies for the first time on a project. with each field development, it is not one technology, but rather the To justify these risks, operators require that: 1) the technology combination and integration of multiple technologies from mul- bring a minimum of a 30% to 40% cost savings incentive, or 2) the tiple vendors which enable subsea technologies to work together technology is the enabler for the project to proceed. Either way, to achieve the desired results. Because of the huge importance of these are key drivers for operators to use subsea processing tech- integration, the role of one supplier to integrate and package the nologies on their project. systems becomes critically important to the project.

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JIPs (joint industry projects) are another In December 2018, MAN Energy Solutions’ first subsea compression trains at Equinor’s path for bringing subsea processing tech- Åsgard field had achieved 50,000 operating hours with nearly 100% availability. This nology to the market. A JIP consists of a achievement helps operators to have greater confidence in the technology. And industry specific group of operators and contractors experience with gas compression helps other operators to reduce the level of risk for their working together to mature the subsea pro- field development conceptual studies. According to Equinor, the subsea gas compression cessing technology from conceptual studies technology on the Åsgard field will increase the reservoir’s productive life by 15 years and through testing and piloting, and eventu- add 282 MMboe in reservoir recovery. ally installation and operation. LONG-DISTANCE TIEBACKS SUBSEA COMPRESSION Pseudo dry gas systems are an emerging technology in subsea gas production boosting TECHNOLOGY that is a promising, economically viable alternative to compression systems for long tie- Table 1 of the 2019 Subsea Processing backs of an approximate 100 km (62 mi) or greater. This innovative technology adapted poster shows two major compression from surface applications helps overcome the pressure losses due to gravitational affects projects (Åsgard and Gullfaks South Brent) in long tiebacks and deepwater depths. which are currently operating. The success of these projects is providing the industry with confidence in subsea gas compression, and more operators are now concep- tually evaluating subsea gas compression on other projects. These potential subsea gas compression projects are indicated in the “Current Status” column of Table 1 with a “C” for “Conceptual Project. Unfor- tunately, only publicly announced gas compression conceptual studies can be listed on the poster. However, according to the contractors and system integrators, many more such studies are under way but are confidential at this time. Chevron has publicly indicated that sub- The Åsgard field contains sea gas compression is being conceptu- what is believed to be world’s longest subsea ally evaluated for the Jansz-Io fields which gas production tieback. would negate the need for a multi-billion (Courtesy Equinor) dollar offshore floating host platform. This is a prime example of the potential for technology to produce a significant cost saving This year’s Subsea Processing poster highlights a combination of technologies that in that far outweighs the risk introduced by the future will enable operators to recover stranded gas fields using long-distance sub- using the technology. In the case of Jansz-lo sea tiebacks. The combined technologies of INTECSEA’s Pseudo Dry Gas liquids removal the cost savings would be significantly unit plus Fuglesangs Subsea AS’s (FSubsea’s) Omnirise miniboosting system with Voith’s greater than the 30% to 40% threshold. integrated variable speed torque converter and magnetic coupling will enable liquids to The risk of certain “unknowns” is be separated within the flowline and therefore increase gas flow. The removed liquids are reduced for operators considering subsea then pumped through tubes in the umbilical or a small diameter liquids line to the host gas compression as Equinor gains expe- facility. The gas in the flowline contains less liquids after going through this separation rience and publicly shares information process inline of the flowline. With dryer gas in the flowline gravitational losses decrease about their technical success and “lessons and the production throughput greatly improves. learned” from their Åasgard and Gullfaks South Brent projects. ELIMINATING VARIABLE FREQUENCY DRIVES The timeline for bringing subsea com- Another technology is evolving due to the collaboration agreement between FSubsea and pression technology from concept to Voith. FSubsea has integrated Voith’s torque converter in its Omnirise Subsea pump. See Åsgard’s first compression gas was 20 years. the green box on the poster entitled: “Subsea Boosting Technology.” Conceptual development studies started in The significance of combining these two technologies is to eliminate the need for a 1985, and operations started in September VFD (variable frequency drive) on the topsides or on the seafloor as a separate piece of 2015. Future gas compression projects will equipment. This also eliminates the need for certain topsides equipment, hydraulic fluid be much faster due to the shared learnings connection, and signaling flying leads. FSubsea anticipates that its Omnirise Boosting from the Åsgard and Gullfaks projects. System (1.5 MW pump shaft power) will be TRL-4 by 1Q 2020.

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SUBSEA WATER INJECTION production tieback at 35 km (22 mi) using a subsea boosting Another technology that is maturing through the technical system. This tieback record is 50% of the length of the longest readiness level process is NOV’s Seabox subsea water treat- natural flow subsea tieback distance – Shell’s Penguin A-E field ment unit and SWIT Technology. According to NOV “the water tieback of 69.6 km (43.4 mi). In the next five to 10 years, it is treatment is done directly at the seabed and the treated water anticipated that a combination of technologies applied to the is pumped straight into the injection well.” The SWIT Technol- right project will enable boosting tieback distances to exceed ogy provides the quality of water needed for injecting water in natural flow tieback records. Operators and contractors are the injection wells “where it is needed and when it is needed.” working together to close this gap. Note that Åsgard is the lon- This emerging technology will reduce space and equipment gest subsea gas production tieback. on the floating host topsides, eliminate water injection flow- Graph 7 illustrates (as of February 2019) the continued lines and risers, and simplify the subsea hardware for the water advancement of subsea boosting projects for the past 24 years injection system. starting with Eni’s Prezioso field in 1994 at 50 m (164 ft) to Shell’s ConocoPhillips is currently testing the system during the Stones field in 2018 at 2,927 m (9,600 ft). 2018/2019 winter season in the North Sea at an offshore plat- The graph shows how operators slowly gained experience form. It has taken 16+ years of development funded by the and confidence in subsea boosting from 1994 to 2006. During Norwegian Research Council, operators, and NOV in order to this time an average of one subsea processing project per year develop and test the technology. It may become a 20-year effort was installed. Starting in 2007 the number of these projects to get the technology in the field for full time use. installed more than doubled. And in 2014 and 2015, four to five projects were installed. Increasingly, operators are technically SUBSEA TIEBACK MILESTONES and economically evaluating the subsea boosting or compres- Graph 3 from the 2019 Subsea Processing poster illustrates (as sion option as one of their field development options. of February 2019) how the industry has continued to increase the tieback distance for subsea boosting projects. In 2018, Mur- CONCLUSION phy‘s Dalmatian field became the world’s longest subsea oil Evaluation and adoption of subsea processing technologies by operators is not moving as fast and wide spread as contractors had hoped, but subsea boosting and subsea compression projects are increasing in frequency. Some in industry feel that the industry downturn has slowed down the number of subsea TAKE THE PLUNGE! processing projects. However, this downturn has forced contractors and operators to develop more cost-effective solutions which ultimately will help accelerate the use of subsea processing technology on projects around the world. Deepwater Petroleum The emerging technology in the future will allow operators Exploration & Production is to reduce equipment on the host topsides and eliminate some the most comprehensive and equipment on the seafloor. Simplification and size reductions authoritative text available will make the technology less costly and ultimately help to economically justify a more widespread use of the technology. on the business, engineering, No matter what technology is used, the ultimate goal for science, and technology all subsea processing technology is to help operators improve of this multibillion-dollar Best-Selling 2nd Edition! the recovery percentage of the reserves by increasing the pro- industry. ductive life of the field or accelerating the production during • NEW TO THE SECOND EDITION: the field decline. 372 Pages/Hardcover/2011 • New chapters on geology and geophysics, rigs, and service vehicles EDITOR’S NOTE • Greater coverage of engineering and scientif c This issue of Offshore contains the 2019 Worldwide Survey of schemes used in deepwater Subsea Processing Technology poster, the twelfth installment • Final chapter presents the latest technology used in the “third wave” of industry evolution of this industry resource. The primary aims of this poster are to chronicle the development and developers of these systems and to document the continued commitment of oil companies ORDER TODAY! to the application of these technologies. For online access to VISIT WWW.PENNWELLBOOKS.COM OR CALL 800-752-9764! view and download all posters, please visit http://www.off-

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A vessel-based decommissioning approach could reduce costs by as much as 50%, in part due to lower spread rates. (All images courtesy Oceaneering) Vessel-based decommissioning system offers economic alternative Innovative approach employed on North Sea campaigns

FRANCIS MCGEEHAN, DAVID COULL, AND JAVIER FALCON, OCEANEERING

WELL DECOMMISSIONING is traditionally performed from Two major North Sea operators needed a plan for an eight-well drilling rigs due to the complexity of operations and the avail- plug and abandonment (P&A) and well severance campaign in able technologies and methods, which often include risers, the Danish and Norwegian sectors of the North Sea. Because a divers, and explosives. However, rigs are expensive to operate wide range of equipment was needed for different workscopes, compared to vessels, and often do not have the flexibility to the campaign was divided into two distinct phases to reduce change locations on short notice. the operators’ costs without compromising operational effi- Increasingly, operators are looking to a vessel-based ciency or safety. approach—as well as the innovative application of tooling solutions—to not only keep decommissioning project costs PHASE ONE down, but also to reduce non-productive time and safety risks The project’s first phase focused on two wells offshore Denmark. to workers. A vessel-based approach could reduce costs by as Work involved casing cutting and pulling and annulus perfora- much as 50%, in part due to lower spread rates and the abil- tion on a mudline suspension well. However, the most signifi- ity of vessels to quickly move. Additional cost reductions are cant challenge of the campaign’s first phase was presented by achieved through the ability to live stream operations, which the second well. This well had a temporary abandonment (TA) enables faster decision making and allows some operations cap that needed to be removed, and the potential existed for to be controlled remotely. Further cost reductions also can be retained pressure to be found below the TA cap. realized with multi-client campaigns where mobilization and Previous attempts to safely gauge pressure below the TA cap transit costs are shared. using standard procedures had failed due to an unusual field Oceaneering employed a vessel-based approach in 3Q 2018 for modification made 30 years ago. In case operations had to be the most recent phase of a six-year decommissioning campaign. suspended, the physical tooling solution’s final arrangement also

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needed to be capable of being left in situ without concern for expected, requiring a bridge plug be mobilized from shore. an uncontrolled release of hydrocarbons into the environment. Since starting work for this operator in 2012, Oceaneering has The decommissioning team and supply chain partners deter- conducted P&A operations for 28 suspended exploration and mined they would need to source existing oilfield equipment appraisal wells, mostly mudline suspension wells drilled between that could be quickly and cost-effectively repurposed to offer 1966 and 1998 in water depths ranging from 110 ft to 237 ft. a competent technical and commercial solution. Instead of employing normal drill pipe intervention techniques, the team PHASE TWO used an annular BOP as a stripper, mating it to a proprietary The project’s second phase—conducted from the offshore con- slip-lock conductor connector, in a new tooling configuration struction vessel Olympic Zeus—centered on well cementation, called the conductor stripper assembly (CSA). well severance, wellhead recovery, debris clearance and seabed The CSA was tested and then deployed in combination with clearance survey activity for six wells offshore Denmark and a specially constructed workstring arrangement. The work- Norway. The integrated project team was provided with well string arrangement allowed for the subsea containment, moni- data, well-specific work programs, wellhead severance tooling, toring, venting, fluid diversion, and automatic pressure relief of the Olympic Zeus and a Magnum work-class ROV. any potential well fluids—all while allowing the workstring to Beyond the normal scope of supply, the team also deployed operate with a mixture of manual-operated equipment (chain an existing cement support tool (CST) in a new manner. To tong) and mechanical-operated (drill pipe tongs) equipment prevent cement from slumping inside a well, a retainer is typi- and without returns to the vessel. cally set—usually a mechanical plugging device such as a bridge The CSA was deployed with plug—inside the wellbore at the MV Island Valiant vessel. The the lowest elevation that the project team also enabled 24/7 cement plug will be set. How- live streaming of subsea oper- ever, this method can be both ations direct to the operator’s complex to run and expensive project team. The live stream- due to the one-time use of the ing improved efficiency as it component, additional equip- allowed the onshore teams to ment requirements and need for review what was occurring in additional personnel offshore. real time. It also eliminated the First, the CST was placed need to send video clips and inside a deployment stinger images and descriptions back tool. Next, a water hose was and forth for discussion, or for then attached to the top of an operator to send a repre- the stinger. Finally, water was sentative offshore to monitor pumped down the hose into the A vessel-based approach was employed in 3Q 2018 for two North operations. Sea operators that required a wide range of equipment. stinger, which in turn pumped The first well that the team water out of the CST tool, worked on was prepared for the subsequent setting of a sur- allowing it to open and set at the required depth. The CST was face cement plug. The second well was inspected, the condition deployed with the vessel’s 20-ton offshore construction crane verified and original equipment manufacturer documentation and guided into place by the ROV. provided to the client. Finally, all the wellheads were cut 10 ft below the mudline (sea- The first phase not only marked a new application of existing bed) using the patented abrasive water jet cutting technology tooling, but also was conducted from a vessel instead of a jackup developed by Oceaneering, and all debris was recovered so the drilling rig. This particular operator first approached Oceaneer- seabed was returned to its original state. All project HSE, opera- ing in 2012 for information on the flexibility and cost-effective- tional and KPI objectives of no harm to workers, no high poten- ness of a vessel-based solution for the P&A of North Sea wells. tial incidents, no environmental harm, and no falling objects also Multiple rig moves would have been cost prohibitive as these were achieved without the use of divers, guide wires, or explosives. wells were not in the same area. The campaign’s first phase was completed in 16.5 days, with Using a vessel not only saved the operator the costs of rent- an average of five days per well (excluding transits and mobi- ing and moving a jackup, but also provided the ability to change lizations). The second phase was completed in 15 days, with locations if an unexpected challenge arose. This capability an average of 16 hours per well (excluding transits and mobi- allowed work to continue while a solution for a challenge was lizations). Using a vessel-based approach to decommission- simultaneously developed. During the campaign, the vessel had ing substantially reduced the transit time to and from the site. to change locations when the TA cap encountered proved to be As the oil and gas industry continues to focus on cutting a different type than that specified in records. Due to this dis- costs and reducing workers’ exposure to safety risks, the use covery, the TA cap assessment had to be performed onshore. of a vessel-based approach to decommissioning will likely con- The top of an existing bridge plug was also found deeper than tinue to grow in the years to come. •

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1903OFF47-48.indd 48 2/28/19 4:03 PM EQUIPMENT & ENGINEERING • Production optimization platform offers enhanced predictive failure analytics

WEATHERFORD INTERNATIONAL plc has announced a major enhancement to the ForeSite production optimization platform. Among the top features of the new release is expanding predictive failure analytics to electric submersible pumping systems (ESPs) and adding complete optimization capabilities for plunger-lifted wells. The platform is deigned to expand on its ability to reciprocate rod lift by adding predictive failure analytics for ESP systems. By predicting an ESP failure before it happens, the company says that this capability not only reduces failure frequency, it also reduces total downtime and lost production by enabling proactive failure management and planning. Adding plunger-lift optimization builds on previous optimization capabilities in rod lift, gas lift, natural drive, and ESP-lifted wells. Rather than the status quo—using a trial-and-error method to adjust operating pressures— ForeSite enables real-time optimization and surveillance along with intelligent alerts, well modeling, plunger-cycle design and more. Weatherford also says that the platform is now also edge-computing ready. Combined with advanced IoT-enabled hardware and CygNet SCADA software, placing ForeSite modeling capabilities at the wellsite can increase asset Weatherford says that its enhanced ForeSite offering now provides predictive failure profitability, productivity, and uptime. analytics for ESP systems and complete optimization capabilities for plunger-lifted wells. The capability paves the way for the next-generation automation system, ForeSite Edge, the company says. across wells, reservoirs, and surface facilities on a single, secure platform, in Finally, Weatherford says that the May 2017. enhancement includes automated well “Since its launch, ForeSite has been deployed around the world with unmatched testing and the ability to execute well- success, enabling operators to identify and prioritize their production opportu- work activities in the field via ForeSite nities,” said Kyle Chapman, President of Production for Weatherford. “Simply Mobile. put, the new ForeSite release gives operators the field-wide intelligence that they Weatherford first introduced the need to monetize their data. The new capabilities added to ForeSite combine an platform, which combines phys- unprecedented ability to monitor performance and recognize current and future ics-based models with advanced data improvement opportunities across all reservoirs, wells, surface equipment, and analytics to improve performance pipelines. This is the field of the future.” •

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1903OFF49-53.indd 49 2/28/19 4:03 PM • EQUIPMENT & ENGINEERING Crane adapted for deeper water wind farms

STUART SMITH, SPARROWS GROUP

NEAR-SHORE WIND FARMS are traditionally located in water depths of up to 30 m (98 ft), with mono-pile foun- dations mounted to the seabed. Typi- cally, standard davit cranes with short fixed booms are deployed from these installations to lift and lower materials from supply vessels. However, as wind farms move into deeper waters, the foundation changes to a lattice or jacket with a wider footprint, increasing the crane’s radius requirements in order to reach the supply vessel. This in turn creates a need for a more traditional offshore-type crane with greater functionality. Sparrows Group has devised a new lifting solution, the WindMaster crane, to accommodate the larger structures in deeper waters. It employs an 8-m (26- ft) boom with full powered slewing, luff- ing and hoisting functions that allow it to access decks of supply vessels even in higher sea states. Recently the company signed a contract to supply 103 Wind- Master cranes for installation at Scot- tishPower Renewables’ 714-MW East Anglia ONE wind farm off the Suffolk coast in southeast England. This is due to generate first power later in the year and should be fully operational by 2020. A crane will be installed on each of the farm’s 102 wind turbines with a further crane used for training purposes.

STRENGTH ASSESSMENT All cranes have a deflection rate – an ability to flex so that they can absorb the loading forces that come from lifting a heavy weight in a dynamic situation – and accuracy was critical in order to reduce the load impact of the new design. Ropes provide most of the required deflection due to their flexibility: one of the main challenges was to optimize the hoist ropes to ensure sufficient strength to comply with minimum safety requirements but at the WindMaster crane under development. (All Images courtesy Sparrows Group) same time not to the extent that they

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Hydraulic apprentice under supervision.

became too rigid, as this which would increase the dynamic forces that affect the specification of all the other crane components. Unmanned wind turbines require regular maintenance and a robust protection system is a must to prevent corrosion. Cranes on offshore turbines are generally 15-25 m (49- 82 ft) from the water line: as steel naturally corrodes in this environment, alternative materials were adopted where possible for the new design such as nylons, GRP and stainless steels. A protective paint system was applied with care taken to avoid potential contact with or chipping of the coating that might degrade the corrosion resistance. For areas of Sparrows has transferred its knowledge from years of expe- the crane where stainless steel and general carbon steel are rience in the offshore oil and gas industry for the new off- in contact, an insulator was applied to limit the impact of shore crane. As the renewables sector continues to expand accelerated galvanic corrosion that can often occur between and evolve, new challenges will emerge, and the supply chain these materials. must be prepared to adapt and meet those needs. • Due to a lack of regular accessibility once deployed in-field (since the turbines are unmanned), reliability of the crane THE AUTHOR would be critical. To eliminate the chance of water ingress Stuart Smith is head of design and technology and material deterioration a PTFE coating protection was at Sparrows Group. applied on steel components in combination with a marine sealant. For pinned connections, a two-part xylan coating was adopted consisting of a xylar hard bonding agent with a xylan PTFE coating on top, which insulates the material. Nylon was used for the crane sheaves and spacers inserted between any moving components to provide wear protection.

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1903OFF49-53.indd 51 2/28/19 4:03 PM ᶁ EQUIPMENT & ENGINEERING Motion compensation technology improves decommissioning operations

VINCENT THÖNISSEN, AMPELMANN

DECOMMISSIONING DONE SAFELY and efficiently is what clients expect, especially so in the North Sea. Ampel- mann, an offshore access solutions and services provider, has seen a rise in the demand for its technology to enable the safe and efficient transfer of personnel, utilities, and cargo during the late life and decommissioning of offshore platforms. Over the past year, the company has worked together with a heavy-lift marine contractor to help prepare an offshore platform in the southern North Sea for decommissioning. With the use of the Ampelmann A-type gangway system, the client was able to reach the multiple landing locations necessary to remove the platform in parts. The A-type also provided a safe escape route An Ampelmann gangway system assists decommissioning of an offshore platform. in the case of an emergency. (Courtesy Ampelmann) More recently, the company worked on and completed a short shutdown Ampelmann is working with the Oil & Gas Technology Centre (OGTC) to campaign to allow production-enhanc- develop a life support solution that enables clients to keep operational costs low ing work to take place. during late life and decommissioning. Launched in February 2017, the OGTC is a The main challenge in the late life not-for-profit, research and knowledge company, which aims to become the go-to and decommissioning stages of a plat- technology center for the oil and gas industry in the UK and globally. form is maintaining efficient opera- The concept that the two companies are working on essentially uses motion tions. Production is decreasing steadily, compensation to provide a host of services year-round to maintain aging and while it still takes resources to keep all dormant facilities awaiting final lift preparations. Utilities such as water, high utilities functional. The key is in find- pressure air, diesel, and power can be delivered with personnel on a dedicated ing innovative offshore solutions that vessel. It is a scalable, modular, and a re-useable system along with being capable can keep the last two aligned. of providing piece meal decommissioning services also by use of its innovative One of the largest decommissioning motion compensated lifting platform. expenses for an asset owner is the oper- OGTC and Ampelmann are in the feasibility stage of the project actively look- ation of the facility, including power ing for industry input and potential partners. Decommissioning as well as most generation and utilities, also known of the offshore access industry is becoming increasingly collaborative. It is plug- as ‘life support’ systems, from when it ging in the right solution at the right time. By working together, various industry ceases production to completion. stakeholders can combine innovative solutions and services to get the most out With full motion compensation tech- of their decommissioning operations. ᶁ nology, operational costs are optimized by extending the weather window, decreasing the duration of campaigns, and providing alternatives to capital-intensive assets, such as jackup rigs and heavy-lift vessels.

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This sample of Magma’s m-pipe is about to undergo a burst test and has been fitted with strain gauges to record effects as pressure inside the pipe increases. Displacement transducers will record any movement of the end fittings relative to the pipe. (Courtesy Magma Global) HWCG selects m-pipe for emergency well containment riser HWCG, A DEEPWATER oil and gas emergency response con- The consortium’s members have identified a range of poten- sortium for the US Gulf of Mexico, has commissioned Magma tial demanding containment scenarios requiring high-pressure/ Global to qualify m-pipe for a 350°F (177°C), 15,000-psig rated high-temperature performance. HWCG selected m-pipe for its riser to augment its emergency well containment system. pressure and temperature performance, its lightweight and flex- The lightweight, flexible m-pipe section, HWCG claims, will ible properties which enable heave compensation at the base enable a quicker response in shallow waters and for floating of a steel riser, because it is suitable for a wide range of fluids, production facilities where vertical access may be a challenge. provides low frictional resistance, and is resistant to abrasion. The flexible riser would remain in a ready-for-deployment Andy Butcher, Test Engineering Manager at Magma Global mode on the US Gulf Coast for deployment following a subsea said: “The m-pipe design has already undergone extensive test- well blowout. When installed to capture hydrocarbons it could ing, both to assess materials properties and performance of remain in place for up to six months while a relief well is drilled. the carbon fiber composite pipe, and the interface of end fittings The company says the design envisions approximately 800 ft to the pipe under typical operating conditions. The operational (244 m) of m-pipe connected on one end to a rigid riser and on requirements for the HWCG applications are at temperatures the other end to the incident well. The m-pipe will form a lazy above the normal test conditions. Therefore, Magma will carry wave between the two rigid ends thereby decoupling motions out additional testing to confirm m-pipe performs satisfactorily and improving operability. Using a temporary flowback solu- at elevated temperatures for deployments of up to six months. tion, hydrocarbons are processed via the riser system and then “These additional tests will include assessing the perfor- collected in tankers for transportation. mance of the pipe and end fittings while subjected to the pres- The consortium requires the flexible section to be lightweight sure and higher temperatures required for HWCG. Burst tests and easy to handle offshore to enable rapid deployment. It must will be used to determine the pressure that failure occurs. There also be resistant to degradation with continuous exposure to will also be tests to assess the long-term effects of pressure com- hydrocarbons at temperatures up to 350°F, pressures up to bined with the HWCG high temperature requirement. This will 15,000 psi (1,034 bar) and water depths of up to 10,000 ft (3,048 involve test items being subjected to a constant pressure while m). Magma will qualify a 6-in. nominal ID m-pipe specimen to also being maintained at high temperature for six months.” • meet the specified project requirements before manufacturing the final pipe order.

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PEOPLE COMPANY NEWS Brian F. Maxted, chief exploration officer and found- Exxon Mobil Corp. says it will ing partner of Kosmos Energy, has retired. The com- streamline its upstream organization pany has appointed Tracey Henderson as chief and centralize project delivery across exploration officer. the company to support its plans to Chevron Corp. has appointed Pierre Breber as double operating cash flow and earn- Friar McWhirr vice president and CFO, effective April 1. He succeeds ings by 2025. Effective April 1, the re- Patricia Yarrington, who has decided to retire after organization will involve creation of 38 years with the company. three new upstream companies. Exx- Effective April 1, Liam Mallon will become pres- onMobil Upstream Oil & Gas Co. ident of ExxonMobil Upstream Oil & Gas Co.; Steve will focus on end-to-end value chain Greenlee will become president of ExxonMobil Up- management in five distinct global stream Business Development Co.; Linda DuCha- businesses – unconventional, liquefied rme, will become president of ExxonMobil Upstream natural gas, deepwater, heavy oil, and Lumsden Wilson Integrated Solutions Co.; and Neil Duffin will become conventional. ExxonMobil Upstream president of ExxonMobil Global Projects Co. Business Development Co. will over- MODEC has appointed Yuji Kozai as president see strategy development, exploration, and CEO and Toshiro Miyazaki as chairman of the acquisitions and divestments and ac- board. tively manage the upstream portfolio. US President Donald Trump has nominated David ExxonMobil Upstream Integrated Bernhardt as Secretary of the Interior. Solutions Co. will provide technical Eugene T. Coleman, executive vice president, and specialized commercial skills, such Sledzik Musayev Exploration and Business Development at Murphy as drilling, research and technology, Oil Corp., has elected to retire after 17 years with the gas and power market optimization, company. Michael K. McFadyen has assumed re- and the global deployment of sponsibility for Exploration and David R. Looney resources. for Business Development. SBM Offshore is adopting a new Wintershall Middle East has appointed Helge resourcing model to support antici- Beuthan as general manager. pated growth in demand for offshore MHWirth has appointed Pete Miller as executive engineering services. It will involve not Bradshaw Misner chairman and Eirik Bergsvik as CEO. only recruiting new engineering staff, Schlumberger has named Olivier Le Peuch as but also a much higher degree of sub- COO. contracting of partner companies and Hoover Ferguson has appointed Kevin Friar as individuals than in the past, giving president. flexibility to ramp up or down depend- Xodus Group has named Caragh McWhirr as ing on market conditions. As part of innovation manager. this new arrangement the company is Ryan Lumsden has joined Saab Seaeye as business creating a ‘high value engineering cen- Clow development manager. Abbott ter’ in Bangalore, India, with long-term ROVOP has appointed Lee Wilson to the newly created role of partner Nauvata which will provide head of technology. detailed design services for SBM Off- Renato Bastos has joined Airborne Oil & Gas as vice president shore projects. The new center will Brazil. initially have a light structure but will Jim Sledzik has joined Saudi Aramco Energy Ventures-US LLC as be able to respond to a rapid growth managing director. in workload. Nizami Musayev has joined Tendeka as area manager in James Fisher and Sons plc has Russia. Whittaker acquired Saudi Arabia-based Murjan Peter Bradshaw has joined Tata Steel as technical sales manager Al-Sharq Marine Contracting LLC. – Energy & Power. The acquisition harnesses local talent Pharma-Safe Industrial has hired DeWayne Misner as executive vice president of to bolster provision in the nearshore health, safety and environmental management. marine construction and maintenance Stuart Clow has joined OPITO as director to support global operations. market. ValvTechnologies Inc. has appointed Mark Abbott as director of engineering and BP Ventures is providing $5 million Keith Whittaker as director of global quality management. •

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in finance to Belmont Technology to support the major’s process, to provide what is claimed to be a simple, flexible and artificial intelligence (AI) and digital capabilities in its Upstream swift method for removing redundant subsea equipment and business. The Houston-based technology start-up has devel- tubulars. ICLT is due to be fully commercialized soon. oped a cloud-based geoscience platform that employs AI. The John Lawrie Group (JLG) will establish a new metal re- platform’s capabilities include specially-designed ‘knowl- cycling and decommissioning base at the Port of Dundee on edge-graphs,’ with BP supplying the platform geology, geophys- Scotland’s east coast after reaching an agreement with Forth ics, reservoir and historic project data. This information is Ports. The two organizations will invest a combined £5 million intuitively linked together, identifying new connections and ($6.46 million) in redeveloping an existing two-acre site to workflows, creating a knowledge-graph of the company’s create a new purpose-built concrete pad. JLG will use it to subsurface assets. BP engineers can ask the knowledge-graph dismantle redundant offshore infrastructure brought ashore questions in natural language, with the technology using AI and for metal processing operations. The company’s metals neural networks to interpret the results and conduct fast division will run the new facility, which is due to be operational simulations. According to BP, the goal is to accelerate the in early 2020, at which point up to 10 new full-time jobs will project lifecycle process, from exploration through reservoir be created. modeling, via a 90% reduction in the time taken for data Ampelmann has opened a new office in Sakhalin, compilation, interpretation, and simulation. The investment Russia. will allow Belmont to grow its workforce, extend Sandy’s ca- SNC-Lavalin Group has opened its new European head- pabilities, and accelerate deployment of the product. quarters at Nova North in Westminster. WellConnection Group, a Norwegian inspection, main- Leonardo has opened its Gulf of Mexico Support Center tenance and repair company, has acquired Peterhead-based in Broussard, Louisiana. The 21,000-sq ft (1,951-sq m) facility Independent Oilfield Services (IOS). This deal marks the provides blade repair, spare parts, and technical support. company’s entrance into the UK market. IOS will change its Bagwell Energy Services has announced plans to create name to WellConnection IOS. 150 new jobs in the next five years and make a $2.5 million Oil Spill Response Ltd. (OSRL) has expanded its member capital investment at its Port of Delcambre fabrication center offer with the launch of an unmanned aerial vehicle (UAV) in Iberia Parish. The investment will add precision fabrication service. The new service aims to enhance preparedness and equipment for process industry piping and vessels, install new response capabilities to better support members’ needs in the bridge cranes, and build a 15,000-sq ft (1,394-sq m) addition event of a spill. OSRL has signed call-off agreements with to its fabrication center and a 4,000-sq ft (372-sq m) addition several third-party UAV providers including Bristow Aerial to its painting-and-blasting facility. The project will retain 46 Solutions, Sky-Futures, and Vertical Horizon Media. The existing jobs while creating 150 new direct jobs. call-off agreements will provide its members with pre-agreed Airbus Helicopters Inc., based in Grand Prairie, Texas, is rates, defined mobilization procedures, and a standardized celebrating 50 years of sales and support for US helicopter approach to managing common preparedness and response operators, while Airbus Helicopters Canada Ltd., located activity. in Fort Erie, Ontario, is marking its 35-year milestone. Global Marine Group (GMG) has acquired a 13.8% interest Bishop Lifting Products has acquired Woods Logging in subsea survey/ROV specialist Rovco. GMG, which has three and Industrial Supply, a spooling services, rigging products, business units – Global Offshore, CWind, and Global Marine wire rope and hydraulic solutions provider. – will work with Rovco to provide wide-ranging subsea solu- Penspen has opened an office in Bogota, Colombia. tions to improve data acquisition. Survitec has opened a new service and distribution hub Subsea equipment rental, sales and services provider in Singapore. Ashtead Technology has formed a strategic partnership with Claxton has opened a new office in Stavanger, Norway. 4Subsea. Ashtead will add 4Subsea’s sensors to its IMR services Wind Point Partners has entered into definitive agree- portfolio, also gaining access to 4Subsea’s specialists in subsea ments to simultaneously acquire and merge Clock Spring production, well intervention, and drilling. In turn, 4Subsea Company Inc. and Neptune Research LLC. The combined should strengthen its position in the global sensor market by business will be named ClockSpring|NRI. accessing hardware and digital services delivered through Danos has reached a tentative agreement to acquire the Ashtead’s network which includes facilities in Aberdeen, Abu assets and business of Shamrock Energy Solutions, a pri- Dhabi, Halifax, Houston, and Singapore. vately held 22-year-old oilfield service company, based in James Fisher Offshore and First Subsea have teamed Houma, Louisiana. The deal is expected to be effective this up to develop internal cut and lift technology (ICLT) for offshore month and will increase the number of Danos employees by decommissioning projects. The development combines James nearly 50%, from 2,200 to 3,200. The closing is subject to certain Fisher’s abrasive jet cutting technique with First Subsea’s ball remaining contingencies. • and taper internal lifting tools, including the Ballgrab gripping

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Improved collaboration can drive down drilling opex

THE OIL AND GAS INDUSTRY was plunged into turmoil However, offshore drilling is also subject to stringent envi- when oil prices crashed in 2014. To get back on track, it has ronmental legislation that has led to the industry being increas- been forced to devise and implement new ways of working and ingly regulated. Environmental taxation, in Europe in particular, embrace new solutions in order to remain profitable, while the is a major motivator for the offshore sector to find new ways

price of oil continues to fluctuate. At the same time, offshore of reducing its carbon-dioxide (CO2) and nitrogen-oxide (NOx) operators and drilling contractors have had to step up efforts emissions. Regulations will only get tougher, so ignoring this to reduce their environmental footprint so as to comply with dilemma is no longer possible. new legislative demands, while at the same time seeking ways To reduce the environmental footprint, some level of capex of shrinking their operating expenditures. investment is unavoidable. This however presents a challenge Effecting sustainable opex reductions is no simple matter. as the capex burden increasingly rests with the drilling con- It involves careful risk management, better cost predictions, tractor, whereas the lower opex achieved by reducing the en- and an increased commitment to remote services in order to, vironmental footprint tends to benefit the oil company. Until for example, maximize the availability of equipment, optimize recently, oil companies have had to bear the cost of fuel as well

fuel costs, and prevent unforeseen issues. With the responsibility as the taxes on CO2 and NOx emissions. However, a clear trend for fuel costs increasingly shifting from oil companies to drilling is now emerging whereby the fuel costs of drilling operations contractors, streamlining these services can have a favorable is shifting from the oil company to the drilling contractor and impact on the profitability of a contractor’s operations. with it, the relevant taxes. Smart technologies are available that enable step-changes A sustainable reduction in energy consumption and emissions in efficient and which provide environmental and financial requires digital mapping and a baseline of the asset’s environ- benefits. One favored way for operators to reduce opex is to mental impact. When this baseline is linked to the relevant switch to unmanned offshore operations. Drilling contractors energy consumption data, it is easy to identify improvement are moving in the same direction, however not at the same areas and to calculate the return on investment (ROI). speed. One example is the ballast control room operator, which In the present uncertain scenarios, the oil and gas industry is no longer an individual role for the majority of floating drilling needs to find new ways of operating and new set-ups to ensure rigs as was the case in the past. sustainable profitability. This requires joint efforts between oil Increasingly technological enhancements are eliminating companies, drilling contractors, and third-party service pro- more personnel positions on rigs. Today technologies are be- viders, with all sharing the gain or pain of an operation. When coming available for running engine control rooms fully un- each party carries a share of the risk but also shares in the re- manned, which is already a standard way of working in the wards, the motivation for collective success is high. marine sector. Manned engine rooms are enforced to ensure For service partners, it means looking beyond mere main- fast intervention in the case of a failure. The industry needs to tenance toward helping the oil company and the drilling con- recognize that technology has advanced, and blackout recovery tractor reduce their opex in a sustainable way, while at the situations are resolved more slowly with human intervention same time improving the efficiency of their operations and than with an automated sequence. ensuring better environmental performance. For drilling con- In the same way, primary DP operations are increasingly being tractors, a growing awareness of, and attention to, the envi- moved onshore. DP operations can be handled in an onshore ronmental footprint may well increase the costs of keeping control center, lowering costs and increasing the flexibility for operations sustainable at all times. On the other hand, a manning the position. Wärtsilä has successfully tested remote drilling contractor’s proven ability to deliver both environmen- DP operations of an offshore supply vessel in the North Sea, tal sustainability and low operational costs will, in today’s controlled from San Diego, California. To draw on a parallel form climate, increase its chance of winning the next oil company outside the industry, remotely controlled military drones are contract. • now deployed routinely for combat operations across continents: in the same may remote offshore operations are now well es- JESPER BONDE, WÄRTSILÄ OIL & GAS tablished and proven to be technically feasible.

This page reflects viewpoints on the political, economic, cultural, technological, and environmental issues that shape the future of the petroleum industry. Offshore Magazine invites you to share your thoughts. Email your Beyond the Horizon manuscript to David Paganie at [email protected].

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The index of page numbers is provided as a service. The publisher does not assume any liability for error or omission. AFGlobal www.afglobalcorp.com/drilling 17 Halliburton www.hal100.com 2, 3 Intecsea www.intecsea.com 5 SALES OFFICES Karmsund Maritime Offshore Supply www.kamos.no 9 Nylacast www.chockliner.com 11 PENNWELL PETROLEUM GROUP 1455 West Loop South, Oceaneering www.Oceaneering.com 15 Suite 400, Houston, TX 77027 TechnipFMC www.TechnipFMC.com/WelcomeChange C4 PHONE +1 713 621 9720 • FAX +1 713 963 6228 Wood www.woodmakeitpossible.com C2 David Davis (Worldwide Sales Manager) [email protected] United States • North America • Central America • South America David Davis [email protected] PHONE +1 713 963 6206 #pnec19 UNITED KINGDOM • SCANDINAVIA •THE NETHERLANDS • MIDDLE EAST 10 Spring eld Close, Cross, Axbridge, Somerset, United Kingdom BS26 2FE PHONE +44 1934 733871 Graham Hoyle [email protected]

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