the gulf of mexico’s leading magazinegogulf.net/uploads/3/5/0/2/35027626/jan_feb_2019.pdfvide...

The Gulf of Mexico’s Leading Magazine

Jan / Feb 2019

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Photo courtesy of Shell

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Cover Courtesy of EPS

www.epsteam.com

Stories from Roger Hooper 6

Offshore Rigs 2018 7Bassoe Analytics Report

Go News Network 8BP Plans for Growth in Deepwater Gulf

Shell Extends Rowan Gorilla VI in Trinidad

Transocean and Chevron sign Rig Contract

Byron Updates SMI 71

Talos Energy Updates Zama

McDermott Awarded BP Trinidad Contract

Ensco Launches CTT 18Continuous Tripping Technology

Will 2019 Be a Better Year? 19 Rystad Energy Report

2025 Predicted Oil Production 23US to Eclipse Russia and Saudi Arabia Combined

A Good Year Turned Bad 24Offshore Rig Backlog Fell in 2018

2018 M&A Record Year 26 Stalls at End of Year

Scrapyards from Hell 28 Graveyards of Ships, Rigs, and People

BSEE Reports 30Bureau of Safety and Environmental Enforcement

BOEM Reports 33Bureau of Ocean Energy Management

Flowline 34New Products and Services

Go Cards 37

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ExxonMobil has announced that it has reached a final investment decision and started construction on a new unitat its Beaumont, Texas refinery that will increase crude refining capacity by more than 65 percent, or 250,000 barrelsper day. The third crude unit within the facility’s existing footprint will expand light crude oil refining, supported bythe increased crude oil production in the Permian Basin.

“With access to terminals, railways, pipelines and waterways nearby, the Beaumont refinery is strategically posi-tioned to benefit from Permian production growth,” said Bryan Milton, president of ExxonMobil Fuels andLubricants Company. “The addition of a third crude unit in Beaumont will enhance the refinery’s competitive posi-tion and truly establish it as a leader in the U.S. refining industry.”

Startup of the new unit is anticipated by 2022. The project is expected to create up to 1,850 jobs during construc-tion and between 40 and 60 permanent jobs once completed.

ExxonMobil previously announced plans to build and expand manufacturing facilities in the U.S. Gulf region aspart of its Growing the Gulf initiative. Growing the Gulf projects include expansion of Beaumont’s polyethylenecapacity by 65 percent, a new unit in Beaumont that increases production of ultra-low sulfur fuels, and a new1.5 million ton-per-year ethane cracker at the company’s Baytown chemical and refining complex in Texas.ExxonMobil and SABIC have also created a new joint venture to advance development of the Gulf Coast GrowthVentures project, a 1.8 million metric ton ethane cracker currently planned for construction in San Patricio County.

ExxonMobil’s integrated operations in Beaumont include a 366,000 barrel-per-day capacity refinery, as well aschemical, lubricants and polyethylene plants. ExxonMobil has approximately 2,100 employees in the Beaumont areaand its operations account for approximately 1 in every 7 jobs in the region.

ExxonMobil Corporation also said it will streamline its upstream organization and centralize project deliveryacross the company to support previously announced plans to double operating cash flow and earnings by 2025.

“We’re simplifying and integrating our upstream organization to better capitalize on the industry-leading port-folio we’ve assembled through acquisitions and exploration success in the U.S. Permian Basin, Guyana,Mozambique, Papua New Guinea and Brazil,” said Neil Chapman, senior vice president.

“Our focus is on increasing overall value by strengthening our upstream business and further integrating it withthe downstream and chemical segments to take advantage of our unique capabilities across the value chain. A clearexample is what we’re doing in the Permian, which includes upstream, midstream and downstream investments,enabling us to maximize value unlike any of our competitors.”

The reorganization will be effective April 1 and involve creation of three new upstream companies --ExxonMobil Upstream Oil & Gas Company, ExxonMobil Upstream Business Development Company andExxonMobil Upstream Integrated Solutions Company.

The ExxonMobil Upstream Oil & Gas Company will focus on end-to-end value chain management in fivedistinct global businesses -- unconventional, liquefied natural gas, deep-water, heavy oil and conventional.

ExxonMobil Upstream Business Development Company willoversee strategy development, exploration, acquisitions and divestmentsand actively manage an upstream portfolio that is considered the mostattractive since the 1999 merger of Exxon and Mobil. Consolidation ofupstream portfolio management efforts in one organization will furtherstrengthen the company’s ability to optimize portfolio value.

ExxonMobil Upstream Integrated Solutions Company will pro-vide technical and specialized commercial skills, such as drilling,research &technology, gas and power market optimization, and the glob-al deployment of resources.

2019 Editorial Schedule

Issue Ad Deadline Mail Date Editorial Emphasis

Jan/Feb Jan 20 Feb 15 GOM Recovery Issue

Mar/April March 15 April 15 OTC Trade Show Issue

May/June May 15 June 15 Safety/Training Directory

July/Aug July 15 Aug 15 Shale Oil Issue

Sept/Oct Sept 15 Oct 15 Environmental Issue

Nov/Dec Nov 15 Dec 15 New Product Review Issue

is published every other month by Hooper Group

PO Box 86003 Baton Rouge, LA 70879 [email protected]

Roger B. Hooper Founder and Publisher

Go Gulf Magazine is sent FREE toindividuals in the Gas and Oil Industry. © Copyright 2019 All Rights Reserved.

Established 1999

We welcome comments, artwork and photographs,but please call for approval. Hooper Group assumesno responsibility for the validity of claims in connectionwith information appearing in this publication.Opinions expressed herein are not necessarily thoseof the publisher, government organizations or adver-tisers. Although the publisher makes every effort toensure all information published is accurate, The pub-lisher is not responsible for inaccuracies, mistakes,misprints or typographical errors. The publisherreserves the right to refuse any advertising.

It is Grow the Gulf Time

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Go Gulf Magazine

• Approval of major expansion at Atlantis field sup-

ports strategy of growing advantaged oil production

around existing production hubs.

• Recent BP breakthrough in seismic imaging identi-

fies 1 billion barrels of additional oil in place at Thunder

Horse field.

• New discoveries near Na Kika platform provide

additional development opportunities.

• BP expects to grow net Gulf production to around

400,000 boe/d in the next decade.

HOUSTON – BP has announced that it has approved

a major expansion at the Atlantis field in the U.S. Gulf of

Mexico and has also identified significant additional oil

resources that could create further development opportu-

nities around the production hubs it operates in the

region.

The $1.3 billion Atlantis Phase 3 development is the

latest example of BP’s strategy of growing advantaged

oil production through its existing production facilities in

the Gulf. The approval for this latest development comes

after recent BP breakthroughs in advanced seismic imag-

ing and reservoir characterization revealed an additional

400 million barrels of oil in place at the Atlantis field.

Application of the same technology and analysis has

now identified an additional 1 billion barrels of oil in

place at the Thunder Horse field. Elsewhere, two new

discoveries near the Na Kika production facility could

provide further tie-back development opportunities.

“BP’s Gulf of Mexico business is key to our strategy

of growing production of advantaged high-margin oil.

We are building on our world-class position, upgrading

the resources at our fields through technology, productiv-

ity and exploration success,” said Bernard Looney, BP’s

Upstream chief executive.

“And these fields are still young – only 12% of the

hydrocarbons in place across our Gulf portfolio have

been produced so far. We can see many opportunities for

further development, offering the potential to continue to

create significant value through the middle of the next

decade and beyond.“

Atlantis Phase 3 will include the construction of a

new subsea production system from eight new wells that

will be tied into the current platform, 150 miles south of

New Orleans. Scheduled to come onstream in 2020, the

project is expected to boost production at the platform by

an estimated 38,000 barrels of oil equivalent a day

(boe/d) gross at its peak. It will also access the eastern

Rig Managers: Ask about the Special GO GULF Discount

BP plans for significant growth in deepwater Gulf of Mexico

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area of the field where the advanced imaging and reser-

voir characterization identified additional oil in place.

“Atlantis Phase 3 shows how our latest technologies

and digital techniques create real value – identifying

opportunities, driving efficiencies and enabling the deliv-

ery of major projects. Developments like this are build-

ing an exciting future for our business in the Gulf,” said

Starlee Sykes, BP’s regional president for the Gulf of

Mexico and Canada.

The proprietary algorithms developed by BP enhance

a seismic imaging technique known as Full Waveform

Inversion (FWI), allowing seismic data that would have

previously taken a year to analyze to be processed in only

a few weeks. Application of this technology and reser-

voir characterization has now identified a further

1 billion barrels of oil in place at the Thunder Horse field.

BP’s leadership in seismic acquisition and imaging is

a result of sustained investment in technology and high-

performance computing. Following a successful field

trial at the Mad Dog field, further advanced seismic

imaging with ocean bottom nodes and BP’s proprietary

Wolfspar seismic acquisition source is being planned for

Thunder Horse and Atlantis to better understand the

reservoirs. Wolfspar uses ultra-low frequencies during

seismic surveys, allowing geophysicists to see deeper

below salt layers and enabling better planning of where

to drill wells.

BP is also announcing two oil discoveries in the Gulf

of Mexico, at the Manuel and Nearly Headless Nick

prospects.

The Manuel discovery is located on Mississippi

Canyon block 520, east of the BP-operated Na Kika plat-

form. The well encountered oil pay in high-quality

Miocene sandstone reservoirs. BP is expecting to devel-

op these reservoirs via subsea tieback to the Na Kika

platform. BP’s partner in the Manuel discovery is Shell,

which holds a 50 percent working interest.

BP also has a stake in the Nearly Headless Nick dis-

covery located on Mississippi Canyon block 387, operat-

ed by LLOG. The well encountered oil pay in high-qual-

ity Miocene sandstone reservoirs and is expected to be

tied back to the nearby LLOG-operated Delta House

facility. BP’s partners in the Nearly Headless Nick dis-

covery include LLOG, Kosmos Energy Ltd, and

Ridgewood Energy. BP holds a 20.25 percent working

interest.

Over the last five years, BP’s net production in the

Gulf of Mexico has increased by more than 60 percent,

rising from less than 200,000 boe/d in 2013 to more than

300,000 boe/d today. BP is currently the top oil producer

in the Gulf and anticipates its production growing to

around 400,000 boe/d through the middle of the next

decade.

The growth will be supported by recent project start-

ups, including Thunder Horse Northwest and Thunder

Horse South expansions and the Thunder Horse Water

Injection project, as well as the addition of a second plat-

form (Argos) at the Mad Dog field, which is on budget

and on schedule to come online in late 2021.

Future potential developments at BP’s offshore fields

in the Gulf include Atlantis Phase 4 and 5, further devel-

opments at Thunder Horse, Na Kika subsea tiebacks and

Mad Dog field extensions.

BP is a global producer of oil and gas with operations

in over 70 countries. BP has a larger economic footprint

in the U.S. than in any other nation, and it has invested

more than $100 billion here since 2005. BP employs

about 14,000 people across the U.S. and supports more

than 111,000 additional jobs through all its business

activities.

• While BP has reached a final investment decision

(FID) on Atlantis Phase 3, co-owner BHP is expected to

make a final investment decision in early 2019. BP is the

operator of Atlantis and holds a 56 percent working inter-

est, with BHP holding the remaining 44 percent.

• BP is the largest investor in the Deepwater Gulf of

Mexico over the past 10 years.

• BP operates four large production platforms in the

deepwater Gulf of Mexico – Thunder Horse, Atlantis,

Mad Dog and Na Kika – and holds interests in four non-

operated hubs – Mars, Olympus, Ursa and Great White.

• The Atlantis production platform is located 150

miles south of New Orleans in over 7,000 feet of water.

BP discovered the Atlantis field in 1998 and began pro-

duction there in 2007.

• BP is one of the largest leaseholders in the Gulf,

with acreage in about 200 lease blocks.

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Rowan Companies has announced that the Rowan

Gorilla VI (a Super Gorilla class jack-up) has been

extended by Shell in Trinidad. The rig will continue its

current drilling program until approximately March of

2019. Thereafter, the Rowan Gorilla VI will be used for

platform support and accommodations work until

approximately September of 2019, with an option to

extend this work further until November 2019.

Rowan has also announced that the Ralph Coffman,

a 240-C Class harsh environment jack-up rig, has been

awarded a 180-day contract in Trinidad. The contract is

expected to commence in April of 2019. The previously

announced contract with CGX Resources in Guyana will

follow in direct continuation of this program. The Ralph

Coffman is currently under contract with GulfSlope

Energy in the U.S. Gulf of Mexico through its current

well.

Additionally, BP in Trinidad has exercised a two-

well option with the Joe Douglas, a 240-C Class harsh

environment jack-up rig, immediately following the cur-

rent well. These exercised option wells are expected to

last until approximately May 2019. The Joe Douglas has

also received one more two-well option.

Rowan has a fleet of 25 mobile offshore drilling

units, composed of 21 self-elevating jack-up rigs and

four ultra-deepwater drillships. The Company's fleet

operates worldwide, including the United States Gulf of

Mexico, the United Kingdom and Norwegian sectors of

the North Sea, the Middle East, the Mediterranean Sea,

and Trinidad. Additionally, the Company is a 50/50 part-

ner in a joint venture with Saudi Aramco, entitled ARO

Drilling, that owns a fleet of seven self-elevating jack-up

rigs that operate in the Arabian Gulf.

Transocean Ltd has announced that it has signed a

rig design and construction management contract, as well

as a five-year drilling contract, with Chevron USA, Inc.

for one of its two dynamically positioned ultra-deepwater

drillships currently under construction at the Jurong ship-

yard in Singapore. The drilling contract has an estimated

backlog of $830 million USD, excluding mobilization

and reimbursables. The drilling contract is subject to

design, construction, and delivery requirements set forth

in the construction contract.

The rig will be the first ultra-deepwater floater rated

for 20,000 psi operations and is expected to commence

operations in the Gulf of Mexico in the second half of

2021.

In the event of termination for convenience by the

customer, Transocean will be compensated for its incre-

mental 20,000 psi subsea investment in the rig.

Additionally, a termination for convenience occurring

after April 2020, would result in a substantial termination

fee.

The drillship will feature the most advanced capabil-

ities and state-of-the-art technology available including


ConfinedSpaceSpecialistsThe most reliable fleet of

specialized environmental

cleaning equipment in the Gulf

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dual 20,000 psi blowout preventers, net hook-load capac-

ity of three million pounds, 165-ton active heave com-

pensating crane, and an enhanced dynamic positioning

system. The rig’s high reliability power plant will also be

configured to comply with Tier III International

Maritime Organization emissions standards.

“We are extremely pleased to announce that we have

entered into an agreement with Chevron to construct and

operate the industry’s most capable ultra-deepwater drill-

ship,” said Jeremy Thigpen, President and CEO.

“Transocean has a long and storied history of introducing

new technologies that enable our customers to safely and

efficiently access the world’s most challenging reser-

voirs. Adding to that history, we are proud to be deliver-

ing the industry’s first rig capable of drilling and com-

pleting wells requiring subsea equipment rated to 20,000

psi.”

Thigpen concluded: “On behalf of Transocean, I

thank Chevron for their long-standing partnership, and

trust in our capabilities. I also thank the members of the

Chevron and Transocean teams who have spent countless

hours on the development of this game-changing solu-

tion.”

Transocean owns or has partial ownership interests

in, and operates a fleet of 50 mobile offshore drilling

units consisting of 32 ultra-deepwater floaters, 14 harsh

environment floaters, and four midwater floaters. In

addition, Transocean is constructing four ultra-deepwater

drillships; and one harsh environment semisubmersible

in which the company has a 33.0% interest.

Byron Energy Limited has provided the following

project performance and production update at the

Company operated South Marsh Island Block 71

(“SM71”) F Platform.

On the morning of January 14th, the SM71 facility

produced and sold its 1 millionth barrel of oil (gross)

since initial production began on March 23, 2018. To

date the facility has yet to see any produced water and

continues to operate in accordance with our last produc-

tion update (ASX release dated 21 December 2018). The

facility has also produced over 1.3 billion cubic feet of

gas which is approximately equivalent, on a revenue

basis, to an additional 70,000 barrels of oil.

Initial capital investment for the construction of the

platform, the drilling and completion of the three wells,

required pipelines and all seismic acquisition and federal

leasing expenses has also been recovered.

Byron, through its wholly owned subsidiary Byron

Energy Inc. is the operator of SM71 and has a 50% work-

ing interest and a 40.625% net revenue interest in SM71.

Otto Energy Limited group (ASX: OEL) holds the

remaining interest in SM71.

Go Gulf Magazine


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Talos Energy Inc.has provided an update on the

Zama appraisal in Block 7 offshore Mexico. Talos is the

operator of Block 7 in a consortium with its partners

Sierra Oil and Gas S. de R.L. de C.V. and Premier Oil.

The Zama-2 appraisal well is the first of three

appraisal penetrations drilled by the Consortium to better

define the resource potential of the Zama discovery. The

Zama-2 appraisal penetration was drilled in a down-dip

location approximately 1.3 miles (2.1 kilometers) to the

north of the Zama-1 discovery well in an effort to con-

firm the geological model and define the oil-water con-

tact. This initial phase of the appraisal program was suc-

cessfully and safely completed on January 20, 2019,

approximately 28 days ahead of schedule and 25% below

initially projected costs. The well reached the top of the

Zama reservoir at approximately 10,759 feet (3,279

meters) of true vertical depth ("TVD") and has encoun-

tered the following:

• A contiguous Zama sandstone interval of 1,676 feet

(511 meters) of gross TVD sand, materially thicker sand

than the Zama-1 discovery well and slightly thicker than

the pre-drill estimates for the Zama-2 well. The well also

encountered several other thick, wet sands of similar age

directly beneath the main Zama horizon for an aggregate

total of approximately 2,350 feet (716 meters) TVD of

high quality Upper Miocene sands with rock properties

similar to analogous Upper Miocene sands in the Gulf.

• The Zama-2 penetration logged approximately 581

feet (177 meters) of gross TVD oil pay before reaching

the oil-water contact, preliminarily estimated at 11,254

feet (3,430 meters) TVD, approximately 100 feet (30

meters), deeper than the anticipated depth of the oil-

water contact based on the geophysical signature called a

"flat-spot." The preliminary Net-to-Gross factor in this

pay interval ranges from 68-73%, with rock properties in

line with those at the Zama-1 location.

• Preliminary pressure data helped confirm the oil-

water contact depth, complementing the traditional log-

ging results. The pressure data also indicates that this

northern section of the reservoir is connected to the

Zama-1 discovery well. The Zama-2 vertical sidetrack

and the Zama-3 well will provide additional information

about the reservoir connectivity and consistency.

The last objective of the Zama-2 well was to test a

deeper exploration prospect called Marte. Marte was

designed to inexpensively test a higher risk stratigraphic

trap, and although it encountered high quality sands of

consistent geological age, pressures and quality, they

were not hydrocarbon bearing. The information gathered,

however, helps the Consortium with the evaluation of the

aquifer support of the main Zama reservoir and other

possible prospects on Block 7. The testing of Marte, ini-

tially expected to cost approximately $10.0 million, was

significantly under budget and only cost approximately

$2.5 million, both on a gross basis. The entire cost of the

Zama-2 well, including the additional cost to test the

Marte prospect, will be recoverable when commercial

production from Zama commences.

President and Chief Executive Officer Timothy S.

Duncan commented, "We are very pleased with the

results of the Zama-2 well as we were able to achieve our

primary goals of understanding the depositional environ-

ment and the presence of thick sand bodies needed for

robust aquifer support, both of which help with ultimate

recovery. We also confirmed that this section of the reser-

voir has similar or better rock properties as compared to

the Zama-1 discovery well and that the pressure informa-

tion indicates connectivity to Zama-1. Perhaps most

importantly, the oil-water contact was encountered at the

predicted depth, if not slightly deeper."

The appraisal program will continue next with an up-

dip vertical penetration in the Zama reservoir from the

main bore hole of the Zama-2 well, which will be cored

and a drill stem test will be performed. The second

appraisal well, Zama-3, will be drilled to the south of the

original discovery well and will help delineate the reser-

voir continuity and quality in the southern part of the

field and will be cored to be better understand the reser-

voir geology.

McDermott International, Inc. has announced a

significant* contract award by BP Trinidad & Tobago,

LLC (bpTT) for the engineering, procurement and con-

struction of the Cassia Compression Platform, located 35

miles southeast off the coast of Trinidad.

Go Gulf Magazine


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"This award demonstrates how, through strong col-

laboration and consistent project execution, we continue

to build our relationship with bpTT," said Richard Heo,

McDermott's Senior Vice President for North, Central

and South America. "To ensure project execution excel-

lence, we will leverage our One McDermott Way operat-

ing model to safely and efficiently deliver the Cassia

Compression Platform with the highest quality."

McDermott will provide engineering, procurement,

construction, hook-up and commissioning of the 8,928

ton Cassia C topsides, a 3,747 ton jacket and a 793 ton

bridge to link Cassia C with the existing Cassia B plat-

form that currently sits in 223 feet of water. The scope

also includes Brownfield modifications at Cassia B. The

compression platform will be fabricated and constructed

at McDermott's world-class fabrication facility in

Altamira, Mexico – where another recently delivered

project for bpTT, Angelin, was fabricated.

Trinidad Offshore Fabrication Company (TOFCO), a

fabricator in Trinidad, will fabricate the jacket and the

bridge landing frame.

Engineering services will be provided by

McDermott's offices in Houston, Chennai and Dubai,

with the project management team and procurement

being performed from their office in Houston.

This EPC contract follows the completion of a

detailed engineering and long lead procurement services

contract McDermott completed for Cassia C, as well as

the completion of the engineering, procurement, con-

struction, installation and commissioning (EPCIC) con-

tract of the Angelin project for bpTT.

Cassia C is bpTT's third Cassia platform, handling

gas coming from its operations in the prolific Columbus

basin. Cassia C will receive 1.2 billion standard cubic

feet per day (BSCFD) of hydrocarbon gas through new

piping from Cassia B across the bridge. The gas will be

compressed in three gas turbine driven compressors and

returned to Cassia B for export.

Liquids from Cassia C and Cassia B will be com-

bined and boosted for export.

* McDermott defines a significant contract as $250

million to $500 million. The contract was awarded in two

phases, with an initial booking in the fourth quarter of

2018 for early engineering and procurement work. The

remainder of the award will be reflected in McDermott's

first quarter 2019 backlog.

Operating in over 54 countries, McDermott's locally

focused and globally-integrated resources include

approximately 40,000 employees, a diversified fleet of

specialty marine construction vessels and fabrication

facilities around the world. As used in this press release,

McDermott includes McDermott International, Inc. and

its subsidiaries and affiliates.

Go Gulf Magazine


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Ensco plc has announced its Continuous Tripping

Technology™, a new proprietary solution that provides

more efficient and safer pipe tripping and helps to lower

customers’ offshore project costs. The patented

Continuous Tripping Technology, in concert with other

key equipment, sensors and process controls, fully auto-

mates the movement of the drill string into or out of the

well at a constant controlled speed. When deployed dur-

ing offshore activities, Continuous Tripping Technology

enables pipe-tripping speeds of up to 9,000 feet per hour

– up to three times faster than tripping times achieved by

current conventional stand-by-stand methods.

Continuous Tripping Technology can be retrofitted to

both floaters and jackups, and is particularly well-suited

for ultra-deepwater drillships and larger modern jackups.

Ensco recently completed the installation of Continuous

Tripping Technology on ENSCO 123 and commissioning

of this system is currently underway. Upon completion of

the system’s commissioning and the rig’s acceptance

testing, ENSCO 123 is expected to be delivered in March

2019.

President and CEO Carl Trowell said, “Continuous

Tripping Technology is a step-change efficiency

improvement that uses automation and innovative tech-

nology to address a repetitive, time-consuming process

that is ubiquitous in offshore projects today. Tripping

pipe is on the critical path for all drilling and workover

activities and, as a result, meaningful time is spent per-

forming this process over the life cycle of every offshore

well. Continuous Tripping Technology significantly

reduces the amount of time spent tripping pipe, and the

faster tripping time that this technology offers is expect-

ed to lead to cost savings for customers regardless of

water depth or well type.”

In addition to increased efficiencies, Continuous

Tripping Technology makes the pipe-tripping process

safer by using automation to eliminate human error and

personnel exposure associated with the conventional

stand-by-stand method. Furthermore, the constant speed

that Continuous Tripping Technology delivers has the

added benefit of minimizing surge and swab pressure on

the wellbore by eliminating intermittent stopping and

starting as well as excessive peak speeds that typically

occur when using current industry practices.

Mr. Trowell concluded, “Continuous Tripping

Technology is another example of our ongoing invest-

ments in innovation that are focused on developing sys-

tems, processes and technologies to make the drilling

process more efficient and lower offshore project costs

for customers. We continue to see better utilization for

rigs that deliver the greatest efficiencies for customers’

offshore well programs and, given the proprietary nature

of Continuous Tripping Technology, we expect that it

will help to further differentiate Ensco’s assets from the

competition and position us well for future contracting

opportunities.”

• Continuous Tripping Technology can be retrofitted

to both floaters and jackups and is particularly well-suit-

ed for ultra-deepwater drillships and larger modern jack-

ups.

• Enables pipe-tripping speeds of up to 9,000 feet per

hour – up to three times faster than tripping times

achieved by current conventional stand-by-stand meth-

ods. Tripping pipe is on the critical path for all drilling

and workover activities and this step-change improve-

ment uses automation and innovative technology to

address a repetitive, time-consuming procedure.

• Makes the pipe-tripping process safer by using

automation to eliminate human error and personnel expo-

sure associated with the conventional stand-by-stand

method.

• The constant speed minimizes surge and swab pres-

sure on the wellbore by eliminating intermittent stopping

and starting as well as excessive peak speeds that typical-

ly occur when using current industry practices.

• Continuous Tripping Technology significantly

reduces the amount of time spent tripping pipe, and can

lead to cost savings for customers regardless of water

depth or well type.

Go Gulf Magazine

Ensco Launches Continuous Tripping Technology™

Courtesy of Ensco


Go Gulf Magazine

Saudi Aramco’s EPC bid extensions for the Berri

and Marjan Expansion projects alone pushed over $18

billion of offshore commitments from 2018 into early

2019. The additional time will help to ensure that the bid-

ding contractors can focus on their scope and cost-com-

petitiveness. This includes expanding traditional fabrica-

tion strategies outside of South Korea, and evaluating

recent improvements from yards in India, China and the

Middle East. Funding both of these projects would make

Saudi Aramco the operator to fund the largest amount of

offshore greenfield work for 2019. However, they will

not be the only E&P to bullishly sanction offshore work.

ExxonMobil also looks primed to make an offshore

sanctioning splash in 2019. They will be bringing for-

ward over $16 billion of offshore work for sanctioning.

In fact, 2013 marked the last year where the supermajor

brought forward this volume of greenfield, offshore work

for a final investment decision. Continuing their patient,

phased approach in Guyana, they will be looking to bring

the $10 billion price-tag for two phases of the Greater

Liza project (Liza Phase 2 and Payara) forward for sanc-

tioning. This phased strategy is reminiscent of how the

supermajor developed the deepwater Kizomba fields in

the early 2000’s off the coast of Angola. From 2000-

2012, six phases of the overall development were

approved in a systematic manner that enabled lessons to

be applied from one phase to the next. This, in turn,

enabled subsequent developments to reduce costs. In

addition, with their early works campaign underway for

the onshore scope, the Area 4 LNG project in

Mozambique looks well on its way to being approved

this year.

Not every operator appears to have the same clear-

cut sanctioning decisions to make this year. For 2019 to

reach its full sanctioning potential of $123 billion in

commitments, some projects will need to lower their cur-

rent breakeven prices. Nearly half of 2019’s projects cur-

rently have breakeven prices above $40 per barrel (on a

greenfield capex basis). Failure to do so will result in

many projects missing out on sanctioning.

Brazil’s Petrobras presents a prime example of an

operator that will have important funding decisions to

make this year. The company has an offshore portfolio of

$17 billion in greenfield projects up for sanctioning in

2019. However, if their recent bid-extension on the Mero

2 project was any indication, they will not be paying a

premium to chase schedule. In fact, it appears that their

bid-extension was to ensure SBM Offshore could partic-

ipate with rivals BW Offshore and Modec International.

As SBM Offshore has more local content capabilities in

Brazil, Petrobras’s extension will help to ensure their bid

round will be as competitive as possible.

Petrobras has also shown sanctioning patience

through their ongoing Buzios V FPSO tender. Since

being identified as the lower bidder in the first half of

2018, Exmar has been unable to secure financing. Rather

than accept 2nd place Modec’s high day-rate and move

forward with the project, it appears Petrobras is enter-

taining a re-bid to try and combat forecasted breakeven

prices of over $50 per barrel for the project. While sanc-

tioning decisions for most of their portfolio are expected

late-2019, they will continue to be challenged by

breakeven prices above $40 per barrel.

Regionally, South America and Australia hold the

highest percent of at-risk projects. On an absolute capex

basis, Australia will only look to sanction $2.6 billion of

offshore work this year. The Julimar asset, under the

Wheatstone development, appears to be best positioned

to be sanctioned. Woodside announced back in

November 2018 that it would target a final investment

decision on the field in the second quarter of 2019. The

project team will look to complete FEED in the first half

of 2019 to support the investment decision.

While not all sanctioning opportunities are created

equal, 2019 has a solid base of projects that should allow

for growth above 2018’s activity level. Saudi Aramco

and ExxonMobil alone are well on their way to sanction-

ing $34 billion of offshore work. In addition, regions like

Africa appear to have minimal breakeven price risk for

their sanctioning activity. As this year starts off with sig-

nificant sanctioning optimism, more clarity will be given

as operators answer concrete project sanctioning ques-

tions.

Will 2019 Be A Better Year?


k_Pages 20 - 21 Center Ad Spread for 40 Pages_Layout 1 2/1/2019 9:57 AM

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In a major shift, the United States is set to producemore oil and liquids than Russia and Saudi Arabia com-bined by 2025.

In Rystad Energy’s base case oil price scenario, USliquids production is forecast to surpass 24 million bar-rels per day over the next six years, thereby outpacing thecombined output from Russia and Saudi Arabia.

“The United States, having regained its position asthe world’s top liquids producer in 2014, is poised toaccelerate into a league of its own over the next six yearsand eclipse the collective output of its two closest rivalsby 2025,” said Rystad Energy partner Artem Abramov.

Historically, the US, Russia and Saudi Arabia haveconsistently switched places at the top of the global listof liquid producers – measuring crude oil, lease conden-sate and plant natural gas liquids – but lately market-dri-ven US oil activity and production has built significantmomentum. The US has not seen its liquids market shareexceed 50% among the “Big Three” producing nationssince 1970.

“US growth potential could be slowed if oil pricesslide below our base case for extended periods but, aslong as average prices stay above $50, positive US pro-duction tendencies will persist,” Abramov added.

Rystad Energy assumes an average WTI Cushing oilprice of $58 per barrel in 2019 to 2025.

The growth in US liquids production will be drivenby major shale basins such as the Permian in parts ofTexas and New Mexico.

Given the steep production decline rates of shalewells, consistently strong annual capital expenditure(capex) levels are needed in order to deliver on our baseproduction forecast. This corresponds to as much as 20%growth compared to the investment level observed in theUS oilpatch in 2018, while the $260 billion capex levelrecorded in 2014 is not expected to ever be seen again.

Some market participants have voiced concernsabout a possible depletion in resources from core parts ofmajor liquids basins in the US. But there are no indica-tions that such a development will occur any time soon,”Abramov noted. “While Rystad Energy generally appliesa conservative approach when estimating remainingdrilling inventory per acreage, even in the most matureBakken and Eagle Ford basins, about 70% of economi-cally recoverable resources in Rystad Energy’s base caseoil price scenario have yet to be developed.”

Rystad Energy is an independent energy researchand business intelligence company providing data, tools,analytics and consultancy services to the global energyindustry.

By 2025 US oil to eclipse Russia and Saudi Arabia combined

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Go Gulf Magazine

You could say offshore rig owners dug themselves adeeper hole, but that could be misleading.

About six months ago, things were looking prettygood for the offshore rig market (at least on the surface).Momentum (and positive sentiment) was building on theback of more tendering activity and indications that oilcompanies would be spending more on offshore drillingprojects.

New contracts were generally short-term, anddayrates were seeing a barely noticeable upward trend,but things seemed to be moving in the right direction.

Looking back over the year, it’s evident that thishasn’t been the case. And the recent oil price collapseand a general negative sentiment in the global economyhave knocked the market back into 2016 again.

What’s most worrying is the major listed drillingcontractors actually lost backlog since the start of the2018. That means they'll be starting off in a worse posi-tion than they were in at the end of 2017. The market hasmoved backwards.

Yes, utilization has risen Overall utilization in the offshore rig market rose

throughout the 2018. For comparison purposes later inthis article, let’s look at utilization for a selection of 13 ofthe largest drilling rig owners.

This list includes: ARO/Rowan, Borr Drilling,Diamond, Ensco, Maersk, Noble, Odfjell, PacificDrilling, Saipem, Seadrill, Shelf, Transocean, andVantage.

A good year turned bad:

Offshore RigBacklog Fell in 2018

Change in Backlog for Selected

Major Drilling Contractors 2018


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With over 202 rigs working, this group accounts forabout half the number of rigs on contract worldwide.

According to Bassoe Analytics, since January 2018,the group’s competitive utilization rose from around 55%to 61%, and the number of rigs on contract from 182 to202. Could be worse, but it doesn’t tell the whole story.

The problem is that backlog is fallingThis same group of drilling contractors started 2018

with around 410 years of backlog. They ended the yearwith 375 years.

As most new contract awards have been short, back-log expansion has been outpaced by backlog erosion.Without the long-term awards from Saudi Aramco(which has only helped a small number of these ownerslike ARO/Rowan and Ensco), things would have lookedmuch worse.

So over 35 years of backlog needs to be secured inJanuary 2019 just to get back to the January 2018 startingpoint. And remember that the January 2018 backlog wasalready low (due to low fleet utilization).

It’s going to take a lot of fixture activity in 2019 tosee a net increase in backlog in 2019. Major tenders andextensions in Saudi Arabia, Qatar (QatarGas), Brazil(Petrobras), and West Africa will help, and drilling activ-ity is expected to ramp up in the US and Southeast Asia.

But will it be enough?We think so. Aside from the fact that today's backlog

is so low (it'll be starting from a low base), demand inmost segments should continue trending upward. Sobacklog should grow. But the likelihood of it reaching an

acceptable level is now more difficult to attain. We’relooking at 2020 at the earliest for most of the market(harsh environment rigs excluded).

If nothing else, 2018 year was exciting. We saw some major deals, including Transocean's

acquisition of Ocean Rig and the announcement ofEnsco's merger with Rowan. Attrition continued (over60 rigs left the fleet). Sentiment had a good run for awhile as we got a taste of what a stronger market couldfeel like.

The situation 2018 has ended up in sets the stage formore excitement in 2019.

We'll look forward to more consolidation, morerecalibration, more rig retirements, and a real change inrig demand.

Bassoe Offshore is a leading offshore rig brokerage,advisory and project development company based inOslo, Norway with offices in London, Houston, Dubai,and Rio de Janeiro. Our focus is on offshore rig assetsincluding drilling, accommodation and service rigs, aswell as floating production units.

Since 1978, we have established 11 companies in theoffshore drilling and wind turbine installation industriesand executed numerous independent newbuild, charter,and sale & purchase transactions on behalf of clientsworldwide. We also provide market intelligence, rig val-uation, transportation and consulting services to E&Pcompanies, shipyards, financial institutions, and assetowners.

Competitive Utilization for Selected Major Drilling Contractors 2018


Go Gulf Magazine

"Investors continue to demand that companies deliv-er a clear line-of-sight to positive free cash flow," saidDrillinginfo M&A Analyst Andrew Dittmar. "Scale isone piece of the puzzle on how to get there given effi-ciencies in developing larger acreage blocks, optimizingsupply chain logistics to lower costs and G&A savings.Wall Street no longer supports growth for growth sakesand is ready to punish buyers who do deals without aclear profit strategy."

With the precipitous drop in oil prices that broke allsupport levels beginning in early November, the dealmarkets ground to a virtual stall. This came almostimmediately on the heels of perhaps the most talkedabout week in the industry's recent history. In a span ofjust five days, public company consolidation went into afrenzy with Denbury buying Penn Virginia, thenChesapeake buying WildHorse and Encana purchasingNewfield.

The shift towards corporate-level M&A late in 2018also cut into private equities' share of deal activity. Afterhitting a high-water mark in 4Q17 by taking the buyerrole in 46% of deals, private equity's share of acquisi-tions fell to only 7% in 4Q18. Private equity wasn't over-ly active as a seller in 4Q18 either, accounting for only4% of sold deals by value versus 23% in 4Q17.

Private and institutional capital is still highly activein the upstream business and playing an important role.PE-backed companies continue to explore emergingareas like the Louisiana Austin Chalk as well as the mar-gins of more established resource plays. PE capital is alsoready to move in when it feels public markets are under-valuing assets or companies as seen by the letter put out

by Elliott Management addressing QEP's stock perform-ance and including a firm offer to buy the company.

Another clear theme from 2018 was the institutional-ization of the minerals market with deal activity in thissector growing 100% over 2017 with deal value reachingnearly $3 billion. Buyers cross all capital sectors frompublic royalty companies like Kimbell Royalty Partnersto institutional players like Ontario Teachers' PensionPlan to public E&Ps like Continental Resources.

Looking forward into 2019, Drillinginfo expects thepace of oil and gas deal markets to remain impacted byoil price volatility which ultimately provides numerousspecial situation opportunities, particularly for oil equi-ties that have been oversold. According to Brian Lidsky,Sr. Director Market Intelligence, "The straight-line $31drop in WTI spot oil prices from $76 to $45 per barrelfrom the start of October to just before Christmas coin-cided with the risk-off appetite that was pervasive acrossthe capital markets. US E&P equities responded largelyin lock-step with the rapid decline. Looking ahead, thereality is that albeit global oil demand may slow some,growth remains unabated and for all intents and purposeshas surpassed the 100 million barrel per day level. Alleyes are on the impact of the start of OPEC+ round twocuts, Iran sanctions plus the trend of global oil demand."

Currently, Drillinginfo quantifies $39 billion of dealsin play in the U.S., of which 50% is located in thePermian. There is certainly high-quality assets in themarketplace and buyers ready to acquire. The only barri-er is bridging the bid/ask price. Historically, if the gaphas widened, deals often come with contingent paymentspredicated on a price or asset performance benchmark.

Corporate Deals Drive U.S. Oil & Gas M&A to 4-year Record ... Before Year-end Stall

$84 billion in 2018 highest since $101 billion in 2014

For Special 2019 Go Gulf Advertising Rates

contact Roger [email protected]


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Top Takeaways from 2018:

• Total of $84.3 billion in 2018 with $20.9 billion in4Q18 and 63% of total value in 2H18.

• For 2018, Permian is again most active area fordeals with $28.3 billion or 33% of total.

• Funding asset acquisitions via an overnight equityraise became virtually non-existent.

• SPAC business model (raise public market cashthen find an asset) continues to work.

• The IPO market for E&Ps remains largely closed. • Royalty markets double and rapidly gain institu-

tional attention.

Outlook for 2019:

• Expect the launch of numerous non-core asset salesfrom public E&Ps with BP likely leading the charge.

• Private equity likely to reemerge as a key buyer onasset deals with willingness to pay for PDP and take riskon upside.

• Markets will reward scale and low-cost leaderswhich translates into richer equity currency for largeplayers to make accretive buys of smaller players.

• Remains to be seen if rapid drop in oil prices willaffect the closing of 4Q18's corporate deals.

• Leveraged E&Ps likely to find themselves underrenewed pressure to take action to improve balancesheets.

Top 10 Mergers & Acquisition Deals of 2018

Drillinginfo delivers business-criti-cal insights to the energy, power, andcommodities markets. Its state-of-the-artSaaS platform offers sophisticated tech-nology, powerful analytics, and indus-try-leading data. Drillinginfo's solutionsdeliver value across upstream, mid-stream and downstream markets,empowering exploration and production(E&P), oilfield services, midstream, util-ities, trading and risk, and capital mar-kets companies to be more collaborative,efficient, and competitive. Drillinginfoserves over 5,000 companies globallyfrom its Austin, Texas, headquarters andhas more than 1,000 employees. Formore information visit drillinginfo.com.


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According to new data released by the NGOShipbreaking Platform, 744 large ocean-going commer-cial vessels were sold to the scrap yards in 2018. Of thesevessels, 518 were broken down on tidal mudflats inBangladesh, India and Pakistan, amounting to a record-breaking 90,4% of the tonnage dismantled globally.

Last year, at least 34 workers lost their lives whenbreaking apart the global fleet. The Platform documentedat least 14 workers that died in Alang, making 2018 oneof one of the worse years for Indian yards in terms ofaccident records in the last decade. Another 20 workersdied and 12 workers were severely injured in theBangladeshi yards. In Pakistan, local sources confirmed1 death and 27 injuries. Seven injuries were linked to yetanother fire that broke out on-board a beached tanker.

DUMPERS 2018 – Worst practices

UNITED ARAB EMIRATES, GREECE and theUNITED STATES OF AMERICA top the list of coun-try dumpers in 2018. UAE owners were responsible forthe highest absolute number of ships sold to South Asianshipbreaking yards in 2018: there were 61 ships in total.Greek owners, beached 57 vessels out of a total of 66sold for demolition. American owners closely followedwith 53 end-of-life vessels broken up on South Asiantidal mudflats.

The ‘worst corporate dumper’ prize goes to the SouthKorean liner Sinokor Merchant Marine. The company,which has been loss-making and is about to merge itscontainer operations with Heung-A, sold 11 ships forbreaking on the beaches in 2018: eight vessels ended upin Bangladesh and three in India, where in April 2018,during the demolition of Sinokor’s PLATA GLORY atLeela Ship Recycling Yard [1], a worker died hit by afalling iron plate.

Norwegian Nordic American Tankers (NAT) - incor-porated in Bermuda and stock-listed in New York - isrunner-up for the ‘worst dumper’ prize. Last year, NATreported having earned USD 80 million for the sale ofeight vessels for breaking. Three were sold to Alang forbreaking and five were sold to breakers in Chittagong.According to local sources in Bangladesh, the cuttingoperations of these ships started without required govern-ment authorisations. The sale of two additional vessels toyards in Bangladesh with particularly poor track recordsand where two workers were killed in 2018, promptedNorwegian pension fund KLP to blacklist the company.

Seven vessels were sold to beaching yards for dirtyand dangerous scrapping by German owner Dr PetersGmbH & Co KG. According to local sources, fitter MdSamiul lost his life while scrapping Dr Peters’ DS WAR-RIOR in December 2018.

Other known shipping companies that in 2018 soldtheir vessels for the highest price to the worst breakingyards include: Chevron, Costamare, H-Line, Louis plc,Seabulk, SOVCOMFLOT, Teekay, Zodiac Group andCMB. Belgian CMB is still under investigation for theexport of the MINERAL WATER to Bangladesh in 2016.

With the oil and gas sector seeing a downturn in thelast couple of years, the GNO Platform has documentedan increase in offshore units that have gone for scrap. Outof the 138 oil and gas units which have been identified asdemolished in 2018 alone, 96 ended up on the beaches ofSouth Asia. Figures include 81 small-sized tug/supplyships and 33 semi-submersible platforms. Well knowndrilling companies are amongst the biggest offshoreplayers that dispose of their assets on the South Asianbeaches. While most assets were exported from eitherEast Asia or America, one driller and cash buyer areunder investigation in Scotland for having attempted toillegally export three platforms that had operated in the

NGO publishes list of ships dismantled worldwide in 2018

Record-breaking 90% of end-of-life tonnage

scrapped on South Asian beaches

Scrapyards From Hell

Graveyards of Ships, Rigsand People


Go Gulf Magazine

North Sea and were cold-stacked in Cromarty Firth. Therigs have been under arrest in Scotland since January2018.

Ship owners are facing increased pressure frominvestors and credit providers to stop selling their shipsto beaching yards. In early 2018, Scandinavian pensionfunds KLP and GPFG were the first to divest from fourshipping companies due to their beaching practices.Today, banks, pension funds and other financial institu-tions are actively taking a closer look at how they mightcontribute to a shift towards better ship recycling prac-tices off the beach, taking into account social and envi-ronmental criteria, not just financial returns, when select-ing asset values or clients.

Losing financing and clients, however, should not bethe only concern of ship owners who continue to usedirty and dangerous scrap yards. In 2018, and for the firsttime ever, a ship owner was held criminally liable forhaving illegally traded four end-of-life ships to Indianbeaching yards. Several other cases of illegal traffic areunder investigation. These cases focus not only on theliability of the ship owner, but also on the responsibilityof insurers, brokers and maritime warranty surveyors. Byunravelling the murky practices of shipbreaking, whichinvolve the use of middle men, or cash buyers, and flagsof convenience such as Comoros, Palau and St. Kitts &Nevis, these cases highlight the importance of conduct-ing due diligence when choosing business partners.

NOTES[1] The Plata Glory was beached in December 2017

at Leela Ship Recycling yard. Leela holds a so-calledStatement of Compliance with the Hong KongConvention issued by ClassNK and claims to be offering“green recycling”.

[2] The EU has published a list of ship recyclingfacilities around the world that comply with high stan-dards for environmental protection and workers’ safety.The EU list of approved ship recycling facilities is thefirst of its kind and an important reference point for sus-tainable ship recycling.

According to the GNO, 138 oil industry supply vessels

and semi-submersibles rigswere cutup for scrap in 2018.


Safety Alert No. 343 Worker Falls from Height into Water

Recently a contract crane mechanic (CCM) fell 81feet into the water below as he was replacing the plat-form crane’s anti-two block control valve. A 10-ft ladderhad been positioned between the overboard handrail andthe crane for the CCM’s use. As the CCM was positionedon the crane skid located seven feet above the deck, herealized that he needed to descend the ladder to retrieveadditional tools. As the CCM repositioned himself ontothe ladder in order to descend, he either lost his grip orhis footing, which caused him to fall backwards over thehandrail and into the water.

High winds prevented the CCM from retrieving a lifevest initially thrown to him, but later he was able toretrieve a vest that had been placed in a life ring. Strongcurrents then caused him to drift further from the plat-form. Approximately 45 minutes after the incident began,a fishing vessel rescued the CCM and transported himback to the platform. The CCM was then flown onshorefor treatment and was diagnosed with fractures of cervi-cal and lumbar vertebrae.

The safe work practices in effect at the time of theincident required the CCM to use fall protection forheights that exceed six feet above the deck. Additionally,Coast Guard Regulation 33 CFR 146.20 requires thewearing of work vests when working near or over water.The CCM was using neither item, nor did the JSA iden-tify falling as a potential hazard that necessitated mitiga-tion.

Therefore, BSEE recommends that operators consid-er the following:

· Review this Safety Alert with all offshore person-nel.

· Ensure procedures are implemented that establishminimum requirements for working at unguarded, ele-vated work locations that are six feet or greater abovefloor/grade level or that present a potential for fall and/orinjury to personnel.

· Verify company and contract personnel working atheights near or above water are knowledgeable and expe-rienced in the work practices necessary to perform theirjob in a safe and environmentally sound manner.

· Review job pre-planning procedures to ensureresponse plans, fall rescue plans, emergency responsenumbers, and fast response craft are included if neces-sary.

· Consider equipment position and hazards whencompleting job pre-planning in order to minimize risk.

· For more information, consult the AccidentInvestigation Report:

(https://www.bsee.gov/sites/bsee.gov/files/sm105-fieldwood-07jul2018.pdf)

Safety Alert No. 344 Chemical Release due to

Containment FailureOperator reported, via the National Response Center,

“a release of 70 gallons of emulsion breaker into the Gulfof Mexico due to equipment failure of a tank” from itsunmanned platform. This chemical is nominally com-posed of 40% xylene, which equates to 196 lbs. byweight and meets the reporting requirements in 30 CFR254.46. The chemical had been stored in a polyethylenetote.

BSEE investigated the spill and found:· The discharge was due to a crack along bottom area

of the polyethylene tote (see photos).· The interior of the tote’s walls showed dimples and

reduced wall thickness throughout the fluid contact area.· The tote was improperly labelled as containing

“Corrosive” versus “Flammable” contents per the SafetyData Sheet.

· The secondary containment pan had filled with rainwater and was incapable of retaining the totes contents.

· The chemical provider states that this emulsionbreaker is shipped in 304/316 stainless steel totes andonly should be contained in same or polyvinylidene flu-oride or polyvinylidene difluoride (PVDF) totes.

Conclusions:· The chemical was stored in an improper container,

as polyethylene totes are incompatible with xylene. Thedegree of degradation/damage caused by improperlystoring the emulsion breaker in the polyethylene tote andits role in the tote’s failure of primary containment is notknown, but is considered a contributing cause.

· The tote was exposed to sun/weather and had beenin service for over five years. The exposure to UV/ele-ments may have contributed to the tank’s failure.

· There should be a means for removing rainwaterfrom the secondary containment, allowing room to con-tain any chemical spillage.

· The tote was improperly labeled which couldincrease risks to personnel and the environment.

Therefore, BSEE recommends that operators:· Ensure the compatibility of storage totes with the

chemicals they are designated to store, in accordancewith the safety data sheet (SDS);

· Properly label all chemical storage containers;· Ensure all personnel are properly trained and fully

understand the implications of the chemicals used ontheir facilities;

· Evaluate and inspect all chemical storage contain-ers and supporting structures to ensure they are fit forcontinued service.

Bureau of Safety and Environmental Enforcement

Go Gulf Magazine

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Safety Alert No. 345 Sprag Brake Clutch Failure

Leads to Near Miss

In October 2018, while lifting a construction laydown box (2500 lbs) from vessel with the platform craneauxiliary line, the crane operator proceeded to raise theload. When the load was approximately 6 feet off of thedeck, the winch failed resulting in the load free fallingback to the deck of the boat. The winch continued tounspool after the load hit the deck causing the rigging toalso fall to the deck. A deckhand on the vessel was ableto avoid the falling load. There were no injuries to per-sonnel or harm to the environment.

The winch was removed from service by the cranemechanic and sent to a 3rd party facility to be pull tested,brake tested and disassembled. During testing, it wasfound that it would randomly fail to hold the load whenthe load was released and then pulled again. A full quar-terly inspection of the crane had been completed with noproblems the week before the incident.

When disassembled, it was found that the spragbrake clutch was not as tight and rigid as normal andwould randomly slip in certain positions. After disassem-bly, the sprag clutch was found to have abnormal markson the outer and inner surface of the sprag componentspotentially caused by shock loading and/or faulty compo-nents.

The crane manufacturer stated that identical or simi-lar components are widely used on cranes in the Gulf.

A Safety Alert is a tool used by BSEE to inform theoffshore oil and gas industry of the circumstances sur-rounding an accident or near miss. It also contains rec-ommendations that should help prevent the recurrence ofsuch an incident on the Outer Continental Shelf.

Additional analysis of the failed components is beingconducted by the crane manufacturer – depending on theresults, testing and inspection procedures may be revised.

Therefore, BSEE recommends that operators consid-er the following:

· Look for warning signs of a sprag brake clutch mal-function (e.g. slipping after the winch stops). Crane oper-ators should report any abnormal behavior to mechanicsand facility management.

· Verify control mechanisms including brakes andclutches for proper operation in compliance with API RP2D C.4.1 (6th edition) and manufacturers recommenda-tions during pre-use, monthly, quarterly, and annualinspections.

· Winches should be periodically disassembled and

all wear items should be inspected for damage. Typicalinspection intervals are one to five years, and may varydepending on frequency of use. Refer to the manufactur-er’s recommendations and applicable industry codessuch as API RP 2D (Section C.4.1). Consider ASMESpec B30.5-2004 (chapter 5-2) for guidance.

· If you do not have records of the last winch disas-sembly and the winch is over five years old, limit use ofthe winch and schedule a disassembly and inspectionsoon.

· Conduct periodic oil sampling and analysis.· Record and trend results over time – high levels or

sudden increases in iron contaminants may indicate seri-ous mechanical problems. Disassembly of the winch maybe required to determine the cause.

· Oil should be changed regularly, typically annually.Use only the oil type specified by the manufacturer.Improper oil may lead to brake clutch slippage.

· Conduct a winch warm-up procedure at crane start-up to help prevent brake slippage. This is especiallyimportant during cold weather.

· Avoid shock loading the crane. If you suspect that acrane has been shock loaded, safely lower the load,remove the crane from service and follow the manufac-turer recommended inspection procedures to verify thatthe crane has not been damaged.

· Review all communications and safety bulletinsfrom crane manufacturers and share them with yourcrane operators, mechanics and riggers.

Safety Alert No. 346 Fractures Found on

Stainless Steel Fittings

In November 2018, BSEE was notified of multiplefitting failures occurring on a Gulf of Mexico facility’schemical injection skid that was recently placed in-ser-vice. The deficiencies observed consisted of cracks alongvarious fitting bodies. These cracks can potentially leadto threatening high-pressure gas releases. Furthermore,unused Parker Hannifin IPD (Parker) 316 Stainless Steel(SS) MPITM fittings arrived at an offshore facility andwere determined to be unsuitable for installation. Parkeris currently reviewing the root cause(s) for these failuresand establishing effective corrective actions. Althoughthe primary type of fitting associated with these fractureshas been identified as the Parker 316SS MPITM, this hasbeen an issue discovered on other manufacturer fittingsthroughout the Gulf of Mexico.


BSEE Safety Alerts are tools used by BSEE to inform the offshore energy industry of the circumstances sur-rounding an incident or a near miss. They also contain recommendations that should help prevent the recur-rence of such an incident on the OCS.

Go Gulf Magazine


Therefore, BSEE recommends that opera-tors consider the following options:

· Identify the Parker 316SS MPITM fittings(as well as fittings of similar design) on yourfacilities and inspect for damage. If cracks orother deficiencies are detected, contact the man-ufacturer directly per Parker’s product qualityalert.

· Schedule more frequent inspections of theequipment that utilize this type of fitting. Applythe fittings to your Quality Assurance /Mechanical Integrity system as a focal point forinspections.

· Include the fittings for review withinfuture facility hazard analyses (if applicable).

BSEE Works to Ensure Safety for Deepwater Production Start-up

NEW ORLEANS - The Bureau of Safety andEnvironmental Enforcement recently conducted its finalpre-production inspection of Chevron’s Big Foot tensionleg platform, moored in the Gulf of Mexico about 225miles south of New Orleans. BSEE deemed it safe foroperation on Nov. 15, 2018, and five days later it sawfirst oil.

“The mission of the Bureau of Safety andEnvironmental Enforcement is to ensure offshore oil andgas companies operate in a safe and environmentally sus-tainable way,” said Amy Pellegrin, BSEE’s HoumaDistrict acting district manager. “Big Foot is the seconddeepwater production facility to come on line in our dis-trict this year and we’ve been monitoring their activitiesto ensure they meet all federal regulations.”

From the time an oil company decides to pursue aproject until it actually begins producing usually takesabout 10 years. In Big Foot’s case, that time was extend-ed by a few years because of technical difficulties involv-ing the 16 mooring tendons during the initial installationin 2015. Those issues had to be resolved before the plat-form could be attached and operated safely.

After the mooring complication, BSEE continued tomonitor Chevron's plans to secure and stabilize the moor-ing lines.

Big Foot’s mooring tendons needed to better with-stand a strong loop current, which is an ocean current thattransports warm Caribbean water through the YucatanChannel between Cuba and Mexico and up through theGulf of Mexico.

“New technologies and innovation are brought intoeach new platform design,” said Devon Hillman, BSEEGulf of Mexico petroleum engineer. “As operators takeon more deepwater exploration and production, theyadapt to the many challenges deepwater brings.”

BSEE’s role is to ensure those adaptations are safeand environmentally sustainable.

BSEE conducted several production safety systemreviews and pre-production inspections prior to approv-ing Chevron’s move to begin production on Big Foot.

“With each physical inspection, we confirmed thatChevron’s schematics, diagrams and plans were accurateand that the systems would operate as designed,”Pellegrin said.

The Big Foot platform is located in the Walker Ridge29 area of the Gulf of Mexico in about 5,200 feet ofwater and it has a capacity of 75,000 barrels of oil and 25million cubic feet of gas per day.

The Houma District is one of five district offices inBSEE’s Gulf of Mexico Region and regulates multipleshallow and deepwater oil and gas platforms, drilling rigsand subsea pipelines.

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BOEM to Publish Call for Information and Nominations for Proposed

Gulf of Mexico Lease Sales

BOEM has announced it will publish in the FederalRegister a Call for Information and Nominations (Call)covering proposed oil and gas lease sales in the Gulf ofMexico Western, Central, and Eastern Planning Areas,except for those areas currently subject to the Gulf ofMexico Energy Security Act of 2006 moratorium.

The proposed sales are included in the DraftProposed Program under the 2019-2024 National OuterContinental Shelf Oil and Gas Leasing Program (2019-2024 National OCS Program). Development of the2019-2024 National OCS Program is still underway --the issuance of this Call does not mean that a final deci-sion has been made to hold the sale under the 2019-2024National OCS Program. Oil and gas lease sales in theWestern, Central, and Eastern Planning Areas are cur-rently scheduled as part of the 2017-2022 National OCSProgram.

The publication of the Gulf of Mexico Call will ini-tiate a 30-day comment period. During this time, BOEMseeks comments from industry on interest in the areasproposed for leasing, including nominations or indica-tions of interest in specific lease blocks within the area.BOEM also seeks comments from any interested partyrelating to particular geological, environmental, biologi-cal, archaeological and socioeconomic conditions, useconflicts, or other information that could affect thepotential leasing and development of particular areas.

Information submitted in response to the Gulf ofMexico Call will be used to help determine what specificblocks within a program area may be offered for leasing,prioritize areas with potential for oil and gas develop-ment, develop potential lease terms and conditions, iden-tify potential use conflicts and potential mitigation meas-ures, and assist in BOEM’s planning and environmentalreview process.

BOEM is also publishing in the Federal Register aNotice of Intent (NOI) to prepare a SupplementalEnvironmental Impact Statement (EIS). BOEM will notmake a decision to approve, disapprove, or require mod-ifications to the proposed lease sales until after the com-pletion of the Supplemental EIS.The Call and the NOIappeared in the Federal Register’s Reading Room onDec. 21, 2018, and was publish in the Federal Registeron Dec. 26, 2018.

Next StepsBOEM will analyze the comments from the Call and

conduct the Area Identification. In this step, based on theinformation and nominations submitted in response tothis Call, BOEM will develop a recommendation as tothe area to be considered in environmental and otheranalyses. Upon approval by the Secretary, BOEM will

then publish in the Federal Register the proposed area forleasing.

Following the NOI, BOEM will begin to prepare adraft Supplemental EIS that will analyze the environ-mental impacts of the proposed action. Upon its publica-tion in the Federal Register, BOEM will solicit com-ments from all interested parties on the draft to informthe preparation of the final Supplemental EIS.

BOEM will carefully consider the analyses con-tained in the final Supplemental EIS before finalizing thearea for leasing.

Trump Administration Smashes Record for Offshore Wind Auction with

$405 Million in Winning Bids

Three companies claim winning bids forMassachusetts offshore wind. Areas could supportapproximately 4.1 gigawatts of commercial wind gener-ation, enough to power nearly 1.5 million homes.

Bureau of Ocean Energy Management ActingDirector Walter Cruickshank announced the completionof the nation’s eighth and highest grossing competitivelease sale for renewable energy in federal waters.Today’s lease sale offered approximately 390,000 acresoffshore Massachusetts for potential wind energy devel-opment and drew competitive winning bids from threecompanies totaling approximately $405 million in win-ning bids. If fully developed, the areas could supportapproximately 4.1 gigawatts of commercial wind gener-ation, enough electricity to power nearly 1.5 millionhomes.

Before the lease is executed, the Department ofJustice and Federal Trade Commission will conduct ananti-competitiveness review of the auction, and the pro-visional winner will be required to pay the winning bidand provide financial assurance to BOEM.

The lease will have a preliminary term of one year,during which the lessee may submit a Site AssessmentPlan (SAP) to BOEM for approval. The SAP willdescribe the facilities (e.g., meteorological towers orbuoys) a lessee plans to install or deploy for the assess-ment of the wind resources and ocean conditions of itscommercial lease area.

Before this lease sale, the highest grossing offshorewind lease sale was held in December 2016 for the leasearea offshore New York that received a winning bid ofover $42 million.

The BOEM has 15 active wind leases. These leasesales have generated more than $473 million in winningbids for nearly two million acres in federal waters.Money received from offshore wind lease sales go to theUnited States Treasury.

Bureau of Ocean Energy Management

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Orbital Gas Systems has been awarded purchaseorders for integration projects totalling $3.3 million froma large Texas-based Engineering, Procurement, andConstruction company during the fourth quarter 2018.The purchase orders, the largest of which originates froma key Gulf Coast customer of Orbital’s with the balancesecured from a second Gulf Coast energy operator, com-prise custom analytical integration systems for two newfractionation units. Orbital will provide complete onlineanalysis systems for process control of the new fraction-ation units and the analysis systems for EPA monitoringof each unit.

Orbital has been working on integration projectswith this EPC and its key customer for several years andthe scope of its work has expanded with each fractiona-tion unit built. Orbital is also expanding its service capa-bilities at this key customer’s request to include the com-missioning of previously installed analytical integrationsystems on the same site, a service it plans to expand toall future fractionation units. Orbital’s current projectwith this key customer will include:

• detailed design; • engineering;• fabrication of approved designs; and, • assistance in field commissioning.Nicholas Clough, president and business develop-

ment lead for the Energy Division, stated, “This latestorder with our key customer also puts us in a strong posi-tion to secure the analytical content of three additionalunits currently in early concept stage and likely to resultin orders over the next two years. Further purchase ordersfor additional scope, including VE Technology sampleprobes and systems, are expected early in 2019 for thesame project.”

CUI Global President and CEO William Clough said,“We’re seeing an uptick in integration projects in andaround Southeast Texas that is being driven by our grow-ing reputation in engineering and design expertise andexcellence that is positioning Orbital as the ‘go-to’ solu-tions provider for the Energy Majors. These purchaseorders are reflective of this growing reputation, and ournew Houston facility is perfectly situated to capitalize onthe many unique projects these companies will be initiat-ing in the coming years.”

CUI Global, Inc. is a publicly traded company dedi-cated to maximizing shareholder value through theacquisition and development of innovative companies,products and technologies.

Orbital Gas Systems has offices in the UnitedKingdom and Houston, Texas. For over 30 years, Orbitalhas developed its portfolio of products, services andresources to offer a diverse range of personalized gasengineering solutions to the gas utilities, power genera-tion, emissions, manufacturing and automotive indus-tries. Orbital's internationally recognized expertise in thenatural gas industry, including bringing together thepatented VE Technology® with the ground-breaking

GasPT device, offers natural gas operators and users acomprehensive engineering array for the next generationof energy metering systems. Orbital is a wholly ownedsubsidiary of CUI Global, Inc.

For more information, please visitwww.orbitalgas.com

Wood has been awarded a $43 million (USD) con-tract by a large-cap midstream company to construct 80miles of steel pipeline in west Texas.

The project will serve to transport natural gas liquids(NGL) across Texas. At peak construction, the project isanticipated to employ 200 people.

Andrew Stewart, CEO of Wood's Asset SolutionsAmericas business said: "This is a strategic pipeline forthe US and we are proud to play our part in deliveringthis milestone project. We have the largest and most ver-tically integrated pipeline project offering in NorthAmerica and this win strengthens our position as a majormidstream player."

Thoma Bravo, a leading private equity investmentfirm focused on software and technology-enabled servic-es, announced that it has agreed to acquire PEC Safety,a rapidly growing contractor management software andsafety learning content provider that helps both hiringclients and contractors manage risk, safety, and compli-ance. The investment recognizes PEC's strong momen-tum and is expected to help the company broaden its soft-ware and content offerings. As part of the agreement, thecompany's management team and founders will retain aminority stake in the business.

Founded in 1993, PEC Safety is one of the largestcontractor management networks in the world, enablingclients to hire and manage safe and qualified contractorsthrough a centralized cloud-based software system. Inaddition, PEC provides licensed proprietary safety learn-ing content to a network of more than 3,000 authorizedinstructors who conduct over 235,000 training sessionsper year. PEC, with its unique combination of a contrac-tor management software platform and proprietary train-ing content, has distinguished itself as a rapidly growing,market leader within the energy industry. PEC currentlyserves over 110 operators and 15,000 contractors in itsmission to bring workers home safely from high-hazardjobs through prioritizing training and contractor manage-ment.

"PEC Safety's partnership with Thoma Bravo willenable us to deepen our core capabilities and expand intoother verticals, advancing PEC's mission to reduce risksand increase safety for workers in hazardous jobs," saidColby Lane, CEO of PEC Safety. "PEC Safety will ben-efit enormously from Thoma Bravo's expertise at imple-menting operating best practices and investing in newproduct functionality and features that will continue toscale the network."

Contractor risk exposure is increasingly being recog-

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New Products and Services

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nized as a top concern in PEC's core market, the energyindustry, as well as other verticals such as construction,manufacturing, transportation and facilities management.PEC is positioned to capitalize on the compelling indus-try tailwinds by offering mission-critical software andlearning solutions that help companies save time, hireconfidently, and most importantly improve safety condi-tions for their workers.

"Thoma Bravo believes there is tremendous growthpotential for the innovative risk, compliance and safetysolutions developed by the talented team at PEC, led byColby Lane," said Hudson Smith, a Partner at ThomaBravo. "Operators are increasingly realizing that theycannot simply outsource risk management to their con-tractors and instead need to put in place robust technolo-gy and learning solutions that provide assurance they areworking with highly-trained, well-qualified and respon-sible contractors."

Thoma Bravo has provided equity and strategic sup-port to experienced management teams of growing com-panies for nearly thirty-five years. The firm has extensiveexpertise investing in risk, compliance, safety and supplychain management software companies, includingRiskonnect, Sparta Systems, Global HealthcareExchange and iPipeline, as well as energy-focused soft-ware companies such as Quorum Software.

PEC Safety is an industry leading, risk-managementcompany that provides a technology-enabled contractormanagement service for reporting and measuring con-tractor risk, safety and compliance information to ownerclients (operators). PEC also develops and offers stan-dardized safety learning programs for workers in high-risk industries. Over 2 million workers have been trainedwith PEC programs by a network of 3000+ PECAuthorized Instructors. For more information, visitwww.pecsafety.com.

Seismos, Inc., a technology provider for the oil andgas industry offering real-time frac treatment and fracperformance evaluation, has secured a $10.5 millionequity financing led by Quantum Energy Partners withfollow-on participation from Javelin Venture Partners,Osage University Partners, ATP fund, Hicks Oilfield andother existing investors. The financing will support thecompany’s growth and future product development.

Seismos’ product, Seismos-FracTM, allows frac engi-neers to dynamically adjust and optimize their treatmentoperations; maximizing future production and ROI. Thetechnology provides a real-time picture of the createdfracture network, a robust understanding of its geometryand characteristics and its ultimate ability to flow-backhydrocarbons into the wellbore – all without putting anyequipment downhole. The technology has already pro-vided valuable insight for thousands of stages across var-ious U.S. shale plays including the Permian Basin, EagleFord Trend, Austin Chalk formation,Haynesville/Bossier Shale and the DJ Basin.

“Unlocking real-time fracture measurements allowsexploration and production companies to customize stagetreatment designs on-the-fly based on direct feedbackfrom the fractures being created, quantify the impact ofeach stimulation variable to the properties of the fracturesystem developed, compensate for variations in geology,avoid frac-hits and optimize well spacing and field devel-opment,” explained Panos Adamopoulos, CEO andfounder, Seismos. “Our success is solely a function ofcustomers increasing their hydrocarbon production atless cost. Our technology is not about incrementalimprovements, but about transforming the productionprofile,” he concluded.

Jeffrey Harris, venture partner at Quantum EnergyPartners, said, “We were impressed by the creativity andeffectiveness of Seismos’ technologies and leadershipteam. The underlying patented technology was devel-oped in collaboration with Stanford University facultymembers and has proven to be tremendously effective forthe initial users, including several of Quantum’s currentportfolio companies. The increasing number of explo-ration and production companies repeatedly usingSeismos’ technology supports the need for additionalresources to meet growing market demand.”

Seismos, founded in Austin, Texas in 2013, hasdeveloped real-time, easy-to-deploy, sophisticated-yet-simple, subsurface technologies that enable producers totake instant action and experience immediate results at anaffordable cost. For more information on Seismos, pleaseemail [email protected] or visit www.seismos.com.

Founded in 1998, Quantum Energy Partners is aleading provider of private equity capital to the globalenergy industry, having managed, together with its affil-iates, more than $16 billion in equity commitments sinceinception. For more information on Quantum, pleasevisit www.quantumep.com.

Stress Engineering Services, Inc., the global leaderin consulting engineering services, has achieved anAmerican Bureau of Shipping (ABS) RecognizedSpecialist certification for its condition based monitoring(CBM) services.

ABS has certified SES’ process for identifying andtracking damage in drilling riser joints, including the tel-escopic joint. The certification will move to a life-cyclecondition based monitoring, maintenance and inspectionsystem approach that is deployed and performed on themobile operating drilling unit (MODU). The CBMapproach will remove uncertainties surrounding damageof riser joints and will allow the owner to determinewhether the drilling riser should be redeployed orreplaced.

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An ABS Recognized Specialist performs specificservices at the request of equipment manufacturers, ship-yards, vessel owners or other clients. They also utilizethe results of inspection, measurements, testing or main-tenance in making critical decisions affecting classifica-tion or statutory certification or services. Certification isa five-stage process, which includes feasibility, conceptverification, prototype validation, systems integrationand operations. The qualifications in each stage includerisk assessments, engineering evaluations and documentreviews, followed by a facility audit.

Chuck Miller, vice president, Stress EngineeringServices, said, “We are proud to be the only companythat is an ABS Recognized Specialist for condition basedmonitoring of drilling riser systems. Our system is com-patible with all present owners’ maintenance programsand ensures that maintenance requirements are supportedwith robust engineering.”

The certification is valid for three years, and SESwill be listed on the ABS External Specialist database.

Since 1972, Stress Engineering Services, Inc. hasbeen a global leader in consulting engineering servicesand solutions for a variety of industries. StressEngineering Services is committed to providing the mostcomprehensive design, analysis and testing services withan unsurpassed level of engineering integrity and skill.The company’s multi-disciplinary engineering methods,advanced technology, innovative applications and highlyknowledgeable and experienced staff provide proven,quantifiable benefits to its worldwide portfolio of clients.Stress Engineering Services is headquartered inHouston, with offices in Cincinnati, New Orleans,Calgary, and Singapore. www.stress.com.

Danos has secured a contract with Equinor for pro-duction operation support on its Titan SPAR platform,located in the deepwater Gulf of Mexico.

The Equinor project began late 2018 and employsproduction personnel on the floating drilling and produc-tion structure located at Mississippi Canyon block 941 ata depth of nearly 4,000 feet. This is Danos’ second jobwith Equinor, as it was awarded a contract for coatingsmaintenance on the Titan platform earlier this fall.

“Danos is excited for the opportunity to work with ahigh-performing company like Equinor,” said ownerPaul Danos. “Securing and executing the details of thecontract has been a true team effort, and we look forwardto continuing our commitment to customer service andexcellence.”

Danos has also been awarded a multi-year contractfor production operations with another major oil and gasproducer in the Gulf of Mexico. As a result of theserecent contract awards, Danos has increased its produc-tion workforce by about 150 new employees. The major-ity of these new positions are production operators whowill be working on the Gulf Coast, with projects span-ning from Galveston, Texas, to Venice, Louisiana.

“Danos’ ability to provide a recruiting and retentionmodel for competent and skilled workers heavily influ-enced both contracts,” said Danos. “I commend Danos’operations team, as well as our human resources teamwho worked closely with our customers’ operations andprocurement teams to make both projects possible.”

Gauthiers’ Oilfield Rental, LLC has changed itsname to Modex, LLC. The name change follows thetransaction between the companies in May 2015 whereGauthiers’ Oilfield Rental, LLC became part of Modex.Modex offers sale and rental of offshore containers, bas-kets, cabins, workshops and support equipment for theoffshore industry.

“We are excited to align our branding with our glob-al team.” says Garett Gauthier, America’s RegionDirector. “Modex continues to invest in state of the artequipment that our customers demand. We have seenpositive pickup in the utilization of our equipment as themarket returns. Our team will continue to strengthen theModex brand in the Americas and our alignment ofbranding will support this effort.”

All branding materials will be updated to reflect thechange. Meanwhile, the existing Louisiana locations (inLafayette, Houma and Port Fourchon) will continueunder the same management while continuing to expandofferings and develop a broader range of products andservices.

Modex has an inventory of more than 18,000 units,a global presence and comprehensive service offeringsfrom engineering and manufacturing to the sale and leas-ing of units. The company currently has operations inNorway, UK, Bulgaria, Romania, The Netherlands,Denmark, Brazil, UAE, Australia, Singapore, Malaysia,Indonesia, Thailand, Saudi Arabia, Qatar, Canada andthe United States.

Modex continues to build its fleet of a full line ofcertified cabins and workshops built especially for thehostile offshore environment. These cabins have severalpotential applications, including cabins, workshops,operating rooms, laboratories, control rooms and offices,among others. Equipment certifications cover majornational and international safety standards, includingIEC, NEC, ATEX, DNV 2.7-1, DNV 2.7-2, EN 12079,ABS, US Coast Guard, SOLAS and NORSOK.Customization options include hoists, electrical coding,fireproof lockers, interior cranes or any other featuresneeded for specific conditions are available.

For more information, please contact: Modex, [email protected] (337) 235-8548

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Oilfield Christian Fellowship www.oilfieldchristianfellowship.com

OCF luncheons and dinners are held in Canada,Colorado, Oklahoma, Texas, Louisiana, Wyoming,and Pennsylvania, with more chapters in the making.Speakers share how they came to know Christ andwhat He is doing in their lives. Because of this, thou-sands of men and women have been encouraged,lives have changed and many have accepted Christfor the first time.

Sign up for our free newsletter at www.oilfieldchristianfellowship.com

Raleigh NepveuxSales

LAGCOE Invitational Golf TournamentFriday, April 12, 2019 | Golden Nugget Hotel & Casino

LAGCOE is pleased to announce the LAGCOE Invitational Golf Tournament to be held onFriday April 12, 2018 at the Golden Nugget Hotel & Casino in Lake Charles, LA .

The golf tournament will be limited to 45 teams filled on a "first-come, first served" basis. The entry fee will be $1000 per 2-man team and includes a Thursday afternoon

practice round, two rooms at the Golden Nugget Hotel on Thursday, April 11, 2019 and a ditty bag for each player. An evening social will be held immediately

following the practice round, and is included in the entry fee as well.

The deadline for entry is March 13, 2019.

At the end of the tournament, prizes will be awarded to the top two individual male and female winners and the top two team winners from each flight.

For more information on the tournament, please contact

Tully Blanchard: [email protected], Corinne Sprague: [email protected],

David Church: [email protected] or Jeff Fooshee: [email protected]

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