1. 1118 Daria Drive, Houston, TX 77079
Roy Shilling Tel (713) 962-6857
Email: roy.shilling@frontierdeepwatersolutions.com
September 2011 1
Education: MS Ocean Engineering, Texas A&M University, 1978
BE Mechanical Engineering, Vanderbilt University, 1976 cum Laude
Experience &
Qualifications:
- Thirty seven years of engineering experience in the field of deepwater oil and gas
development.
- Extensive project experience in floating and riser systems design/analysis and
fabrication.
- Through understanding of deepwater dynamically positioned and moored drilling
and completion operations and the impacts of metocean conditions such as
hurricanes and loop currents.
- Project Delivery Manager for the World’s deepest dual barrier spar production riser
system
- Macondo free standing riser containment system and worldwide capping stack
design and fabrication experience.
- 15 years’ experience in drilling and completion operations/engineering
Frontier Deepwater Solutions LLC
2014 - President
Frontier Deepwater is limited liability consulting company that provides engineering support to deepwater
projects with Operators or their Engineering Contractors. Frontier has consulting contracts with Anadarko,
Chevron, DnV, IFC and Stress Engineering and is working to extend its support capabilities to other projects.
Frontier is currently involved in Appraise Stage work looking at wet and dry tree development options for the
Paleogene in the GoM and 20K drilling and completion technology. We are also actively involved with DnV in
their Global Wellhead Integrity project.
Anadarko
Anadarko is evaluating a 15K+ development called Shenandoah in 5,800’ water depth in Walker Ridge, Gulf
of Mexico. Appraise Stage evaluations comparing wet versus dry tree spar developments were completed in
2014 and Select Stage engineering is currently progressing through the end of 2015. Both 20K subsea
equipment with HIPPS is being developed as well as 20K dry tree riser systems along with a platform rig for
the spar. Prototype hardware qualification for 2015 includes the 20K wellhead system along with external and
internal riser tieback connectors; high strength steel T&C top tension risers and material qualification; and
high pressure topside flexible jumpers.
One of the studies Anadarko has initiated to compare Shenandoah development concepts was to develop
wet and dry tree operational models for drilling, completion and intervention and perform long term time
domain operational simulations using BMT’s SLOOP program. Wet and dry tree drilling and completion well
models were developed along with 4 different intervention models. Representative well production profiles
were created for a couple of different reservoir possibilities and a 100 year time series of wind, waves, loop
currents and hurricanes was generated.
SLOOP takes the drilling, completion and intervention models, along with the long time series of weather
and “drills and completes” the well thousands of time using a Monte Carlo simulation with an event driven
model taking task times in sequence and then applying the appropriate metocean operating limits to
determine whether the task can be completed or must be suspended or abandoned due to weather
conditions exceeding allowable operating limits. Equipment reliability and repair is also included.
20 – 30 year life of field simulations were performed for various development scenarios and intervention
strategies and a large number of comparative performance statistics compiled including for example:

2. Roy Shilling
January 2016 2
1. What is the range of usage of the 20K MODU throughout the field life? (i.e. years 10, 13, 19?)
2. How much is the platform rig used?
3. What is the anticipated usage of the 20K CWOR and what business model makes sense for this $350
million dollar new piece of kit?
4. What is the anticipated cumulative production including interventions?
5. What is the range of total life of field drilling, completion and intervention costs?
Over 100 performance statistics were generated and key values were then used by Anadarko in the reservoir
and economic models. This has provided valuable comparative insight on the range of outcomes that can be
anticipated for the Shenandoah development.
Chevron
Chevron made a 20K discovery at their Anchor well in late 2014 and is proceeding with their own internal
20K technology development program. Frontier Deepwater is engaged with CVX to assist in planning and
prioritization of engineering work scopes for 2015-2016 support to the project.
Chevron has also funded a project to qualify a 15K surface BOP drilling riser. We are ordering 22” x 1.4”
wall Q-125HY (140KSI) with VAM TTR T&C riser connections. This program is very similar to that carried out
for BP in 2009-2010 and summarized in OMAE2010-20904 (reference [1]), as well as the work being done
for Anadarko on Shenandoah. The scope of work includes the following tasks:
 A mini roll of 650’ of V&M TTR riser pipe at the mill in Dusseldorf
o FLUT data for each joint will be acquired from the mill and used to develop the advanced
minimum performance ratings for the pipe
 The pipe will be sent to the Stress Engineering in Houston for testing in early 2016
o The pipe will be threaded and box connections fabricated by VAM USA
o Samples will be prepared with FEA and tested per ISO13679:2002 CALIV (truncated,
combined specimen):
 Make and break testing with and without pin and box coatings
 Sealability
 Fatigue
 Burst testing (CEYP and CEBP confirmation testing as per API 1111)
 A representative test program to demonstrate the technology qualification is
shown below.
BOP Technologies
BOP Technologies (BOPT) is focused on developing the next generation blowout prevention equipment for
the Oil and Gas Industry. We are primarily focused on new shear ram technology that works based on an
internal pressure intensification design that enables us to deliver 5 to 10 million pounds of shear force, 2 to 3
times what our industry competitors can deliver. http://boptechnologies.com/
BOP Technologies Mission Statement is to provide new generation super-shear BOP technology and services
that will shear and seal anything in a wellbore.
Initially BOP Technologies will be focused on providing unique state of the art super shear ram solutions that
will be backwardly compatible with existing BOP’s. These new shear rams will be able to be installed in
existing stacks more than doubling the shear force capability. The old shear rams are simply unbolted from
the existing BOP and the new BOPT Super Shear Rams are installed with the same interfaces. While initially
focusing on retrofitting existing rigs and stacks, ultimately BOP Technologies plan to produce a complete
BOP system using our proprietary design. Not only will we be able to more than double the shear capability,
we also will be able to reduce the size and weight of the stack substantial making it easier to handle and
having less fatigue and weak point effect on subsea wellheads.

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January 2016 3
BP America, Inc.
2012-2013 Global Wellhead Integrity Project – DP Drilling Weak Point Assessment
Project Manager
Well integrity assurance includes comprehensive loss of position and weak point analyses to fully
understand the consequences of a DP system failure for mobile drilling units. Drive-off, drift-off and force-
off events need to be thoroughly analyzed for their potential impact on the “weak link” along the entire
drilling system spanning from the diverter housing at the rig floor; along the riser; through the BOP
equipment and components; through the subsea tree; if present, and down through the wellhead system
several hundred feet below mudline in the conductor and other casing strings.
Specific drive-off/drift-off responses for rigs working on operations are used to provide force, displacement
and time inputs to well specific weak point analyses. Non-linear elastic plastic analysis with detailed 3-D FEA
models is used to evaluate coupled global vessel/riser/BOP/wellhead system responses to better understand
failure modes. The results of this work is focused on improved engineering technical practices and
associated guidance for conducting weak point analysis for deepwater DP drilling and completion operations
on subsea wellheads. Enhanced methodologies and recommended practice was developed.
2011 – 2012, Project 20KTM
Subsea Riser Systems Engineering/Delivery Manager
Project Manager for BP 20,000 psi subsea drilling and completion riser system. Developed 20KTM
MODU
initial designs for both 19.5" ID and 34" ID drilling riser systems, including riser connector capacity
requirements, choke and kill line sizing and load sharing and non-load sharing central tube designs.
Evaluated wellhead requirements for weak point and fatigue. Developed tensioner requirements for systems
working up to 10,000' water depth in the Gulf of Mexico. Assessed loop current and hurricane abandonment
impacts, along with operability and running and retrieving guidelines.
2010 – 2011, Subsea Global Containment System Delivery Manager
Riser System Engineering and Delivery Manager for BP’s global flyable capping and containment project to
provide capping stack connections and adapters to the wellhead, bop/lmrp mandrel and riser adapters for all
operated drilling rigs worldwide. This involved designing, fabricating and testing riser adapters and
wellhead/subsea tree adapters would permit the use of a capping stack on any BOP, wellhead system or
drilling system in use worldwide. This involved comprehensive design interfaces with test stumps, subsea
trees, wellhead systems, BOP's and about 20+ different drilling riser systems being used in BP’s global fleet.
2010, Macondo Free Standing Riser Containment System Delivery Manager
Architect of the FPSO and free standing riser system that was designed, built, installed and operated to
provide containment of the Macondo blowout.
Patents relative to Free Standing Riser Subsea Containment System US 8,960,302 B2
40078-02 Marine Subsea Assemblies
40078-01 Marine Containment And Disposal Systems And Methods
40078-00 Marine Subsea Free-Standing Riser Systems And Methods
In response to the MC 252 Macondo well blowout in the Gulf of Mexico on April 20th 2010, BP successfully
developed, installed and operated the first of it’s kind deepwater subsea containment disposal system. The
system consists of twin free standing risers (FSR’s) tied to the subsea blowout preventer through a series of
manifolds and flexible jumpers and back through an upper flexible jumper to a ship based floating
production system coupled with a large dynamically positioned storage vessel.

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January 2016 4
The containment riser is a freestanding, insulated pipe in pipe production riser with provision to evacuate the
annulus with nitrogen or hot water circulation if necessary for flow assurance. The main components are:
• A suction pile foundation and chain tether;
• A lower offtake assembly with one subsea hub connector between the riser and flexible jumper;
• A lazy wave 6 inch ID flexible jumper to a subsea manifold;
• A dual casing riser string with wet insulation and low pressure nitrogen or hot water circulation in the
annulus for hydrate flow assurance purposes;
• A taper stress joint at the bottom of the riser outer casing;
• An upper offtake assembly for production from inner riser string and nitrogen injection via ROV
• A non-integral aircan system;
• One 6 inch ID flexible jumper to host vessel configured to disconnect from the vessel
The riser system is designed to accommodate flexible jumper installation after the riser has been installed at
both seabed and surface elevations. The upper flexible will connected to the riser during installation from the
drilling vessel and clamped at intervals hanging vertical along the riser. The system was rated for 60,000
bbls/day. It was installed and successfully operated prior the well being capped.
2009 – 2010, GoM Floating Production Dry Tree Well Systems Manager
Developed limit state design methodology for HPHT riser and flowline systems using UT inspection and wall
thickness mapping (OMAE2011-49424).
Responsible for the design, fabrication and installation of all BP spar and tlp riser systems in the GoM.

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January 2016 5
World Wide Webcast for Offshore Magazine on HPHT Dry Tree Riser Technology.
GoM SBU Floating Systems and Risers Technology Coordinator.
2006 – 2008, Paleogene Floating Systems and Subsea Risers Engineering Manager
Responsible for qualifying a 15,000 and 20,000 psi dual barrier dry tree riser system and flexibles for GoM
Spars. This included inner and outer riser materials qualification, threaded connections and riser hardware
from the subsea wellhead to the production manifold on the platform.
Responsible for qualifying a 10,000 psi dual barrier high pressure drilling riser for GoM spars. This included
both Q-125 T&C and X-80 carbon fiber wrapped designs. The carbon fiber wrapped design utilized a Mad Dog
drilling riser steel core and was burst tested in excess of 39,000 psi. Also has application to deep gas jack-up
drilling on the GoM shelf.
Developed the closed centerwell spar configurations for both Kaskida and Kodiak projects and provided support
to the development of BP’s standard spar hull configuration in the GoM. This hull form was selected for the
Mad Dog Phase 2 project.
Evaluated and helped develop the Multi-Column Floater (Horton Deepwater Development) as an appraisal or
early production system concept for Paleogene by leading a 3 phase JIP with Anadarko, BP, Chevron and
Devon.
Project Manager for floating systems and riser studies being conducted to appraise the Kaskida discovery in
6,000’ water depth.
Responsible for qualifying with Flexi-France a 6” ID 20,000 psi 350F flexible production jumper for a Spar or
TLP riser systems.
Provided subsea drilling and completion downtime simulations for the first 5 years drilling and completion
MODU operation on Atlantis.
Project Manager for free standing drilling riser design for the Transocean Development Driller 2.
Awarded the Best Presentation at the 2008 DOT Conference and published an article in Offshore Magazine
during the first half of this year “Developments in Riser Technology for the Next Generation Ultra-Deep HPHT
Wells”.
2003 - 2005, HPHT Floating Systems and Subsea Risers Project Manager
Delivered the GoM High Capacity High Fatigue Wellhead Conductor Material, Fabrication, Welding and Grinding
Standard Technical Practice now being used worldwide by BP.
Project Manager for the GoM Deepwater HPHT Technology Benchmark Study and developed BP Technology
Closure Plans for drilling, completion, facilities, risers, subsea and pipelines.
Project Manager for the GoM Deep Gas Technology Study and developed BP Technology Gap Closure Plans
for drilling, completion, facilities, subsea and pipelines.
Project Manager the DDII drilling riser integrity assurance program and worked with Transocean on delivering
new build Kvaerner CLIP riser system.
Led Deepstar 7302 xHPHT Subsea System Study comparing a full rated configuration to a configuration using
a High Integrity Pressure Protection System (HIPPS).
Delivered Discoverer Enterprise drilling riser instrumentation system.
Completed Horn Mountain Lessons Learned Report and distributed with BP project’s community.

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January 2016 6
Completed Horn Mountain IPA Project Closeout.
1999 – 2002, Horn Mountain Spar Riser Systems Project Manager
Responsible for the design, fabrication and installation of the SCR’s for subsea wells and the 10 well Horn
Mountain top tension dry tree riser system, a multi-year, multi-disciplinary effort resulting in a world record
for the deepest dry tree well system from a floating production facility:
o Dual barrier riser design
o Largest single piece air can riser tensioning system
o Extended vent tube air chambers to increase efficiency during downstroke
o Compliant air can guide system to improve air can fatigue performance
o Lower stem installation through air can and passive clocking of air can and upper stem to
align compliant guides without intervention.
o Design and qualification of ultra slim line external tieback connector
o First MMS approval of “high collapse” pipe specifications for riser design
o Design and qualification testing of fatigue enhanced high torque premium casing connector
for inner riser (VAM TOP FE-ND).
o Led resolution of mudline vented hanger design and developed methodolgy and computer
tools with DnV to assess risk of annular pressure build up (apb). This methodology was
adopted by the Thunder Horse project and used to finalize the apb design for existing and
future wells.
o Developed pullover design, sea floor well layout, riser interference and DnV risk study of
utilization of DP3 semi to drill future wells.
o Developed completion versus drilling rig field life drilling time/cost simulations used to select
completion rig with pullover configuration
o Managed design, fabrication and installation of metocean monitoring system
o Developed composite material buoyancy can prototype design that would allow future well
tensioning systems to be installed with platform cranes and eliminate the need to mobilize a
derrick barge.
o Worked with Holstein and Mad Dog Well Systems Team to relay HM experience,riser design
basis and specification. Other projects that were complete during this time frame included:
o Technip/2H Horn Mountain Comparison of Field Data Measurements with Analysis & Riser
System Robustness Evaluation
o OTC Paper 15385 BP Horn Mountain Spar Risers – Evaluation of Tension and Installation
Requirements for Deepwater Dry Tree Risers
o Horn Mountain IMMS Presentation at Integrity Management Meeting
ARCO Oil and Gas Company
1997 - 1998: ARCO Global Deepwater Riser Technology Program Manager, Dallas
1994 - 1996: Drilling Computing Program Manager, Dallas
1990 - 1993: Drilling Computing Engineering Leader, Dallas
1985 - 1989: Senior Operations Drilling Engineer, Bakersfield
 Worked 2 years offshore on jackups and semi-submersibles drilling and completing subsea wells.
1982 - 1984: Deepwater R&D Coordinator, ARCO Norway, Oslo
1979 - 1981: Deepwater Design Engineer, Staff Engineering, Dallas