1. 1
Challenges and Risk Associated with a
Deep Water Well
David Mayhall
Drilling Engineering Solutions Manager
SPE Evangeline Section luncheon on May 19th Lafayette, Louisiana

2. 2
Agenda
▌ HSE
▌ Geology
▌ Deep-water Challenges
▌ Planning-Data (generic offset for example case)
▌ Generic example preliminary WBS for a Deep-water well
▌ Risk and Challenges Hole section by Hole section
▌ Summary

3. 3
Industry standards and practices that promote reliability
and safety through the use of proven engineering
practices

4. 4
The Deep-water Area Covered in Todays Presentation

5. 5
Oil and Gas Journal article 1990 (Green Canyon 29)
PLACID HALTS ULTRADEEPWATER PROJECT IN THE GULF
4/23/1990
Rick Hagar
Gulf Coast News Editor

6. 6
Quickly Understand the Big Picture

7. 7
Geologic Complexity
References
Zarra, L., 2007, Chronostratigraphic framework for the Wilcox Formation (upper Paleocene Lower Eocene) in the deep-water Gulf of
Mexico: Biostratigraphy, sequences, and depositional systems: 27th Annual Gulf Coast Section SEPM Bob F. Perkins Research
Conference, p. 81.

8. 8
Alaminos Canyon

9. 9
Keathley Canyon

10. 10
Walker Ridge

11. 11
Green Canyon & Atwater Valley

12. 12
Deep Water Challenges
▌ Shallow Geohazards
▌ Pore Pressure – Fracture
Gradient prediction
 Lower and varying
overburden loads
 Narrow operating
windows
Pp
Pw
r/R
Pp
Pw
r/R
Pp
Pw
r/R
Pp
Pw
r/R
Pp
r/R
Pw
r/R
Pp
r/R
Pw
r/R

13. 13
Deep Water Challenges

14. 14
Offset Data
▌ Multiple wells about 20 miles away
▌ One well to the north west about 6 miles away with limited data
▌ Is the stratigraphy the same?
▌ Shallow Hole Hazards the same?
▌ Same basin or mini basin?
▌ What about the Salt?
You need good offset data to evaluate

15. © 2015 HALLIBURTON. ALL RIGHTS RESERVED. 15
Planning and Monitoring
Communicating better with a common goal of improved
performance
▌ Drilling Planning Workflow
▌ Well Construction Requirements
▌ Real-time monitoring

16. 16
Generic example PP/FG/OB Plot (offset 20 miles away)

17. 17
Who did the PP/FG/OB Plot??
▌ Do you need to make your own plot?
▌ Where did the data come from?
▌ Which wells did they use?
▌ Who’s software, what model?
▌ How far away is the data relative to the well you are drilling?

18. 18
36”
26” x 32 ½”
Hole Section
18 1/8” x 21”
Hole Section
16 ½” x 17 ½”
Hole Section
26”
Hole Section
Hole Size
Jet In to Section
Riserless
Top of Salt
End of section
Base of Salt
End of section
TD of Well
Vertical Jetted
Vertical Mud Motor
Vertical Rotary
Steerable
Directional RSS
MWD: Directional LWD:
Gamma / Res.
Mudlogging Samples,
Neutron-Density
Sonic added for salt exit
MWD: Directional /
PWD
LWD: Gamma / Res.
Mudlogging Samples,
Paleo: Monitor
E-Line: TBD
Neutron-Density
Sonic
MWD: Directional /
PWD
LWD: Gamma / Res.
Mudlogging Samples,
Paleo: Monitor
E-Line: TBD
Neutron-Density
Sonic
Riserless
Possible Fault ’Vertical Mud Motor
End of section
End of section
None
MWD: Directional / PWD
LWD: Gamma / Res.
MWD: Directional / PWD
LWD: Gamma / Res.
Target Sand
Target Sand
Target Sand
12 ¼” Open Hole
28” Casing
22” Casing
18” Liner
13 5/8” Casing
Casing Size /
Mud Weights
Directional
Program
Evaluation
Program
Casing / Target
Tops (MD)
Directional RSS
Kick Off Section
12.0 ppg RISER-
LESS
13.0 ppg Pad Mud
12.5 ppg RISER-
LESS
13.5 ppg Pad Mud
11.0 ppg Low ECD
mud
Mud Weight Range
14.0 - 14.5 ppg
Low ECD mud
14.5 ppg
Low ECD mud
Seawater
Preliminary Generic Wellbore Schematic ( ??updated version ??)

19. 19
Preliminary Generic Wellbore Schematic - Correct ?
▌ Does the WBS look light?
▌ Do we need a few more strings of casing possibly?
▌ What about the long string? Possibly set before exiting the salt.
▌ Casing size and hole size change needed
▌ What happens if we change ID? How does that affect completions and
flow?
For the sake of this exercise lets proceed as planned with the
preliminary generic WBS and start to deal with the known risk based off
of the offset data or lack of data for each hole section.

20. 20
Known Risks:
 Verticality while jetting
in 36” conductor
 Shallow Gas hazard
 Shallow Water Flow
 Volume and Pressure
monitoring.
Discussion Points
 Pre-Modeling
 Wellsite Prep
 Operation
 Contingencies
36” Hole Section Generic Example
36” Will be jetted in and the BHA drilling ahead for the 28” section
Wellbore Section
9 5/8”
SperryDrill
Lobe 6/7
-5 stg
NM Saver
Sub
32 ½” DTU
AGR™ Collar
26” Tricone Bit
9 ½” EWR
M5™ Collar
W/DDSR
9 ½” PWD
22.5Ksi
9 ½” DM
Collar
9 ½” MPT
(Neg Pulser)
Float Sub with
Plunger type
float
Transition X-
Over 8” x 9”
Circulating
Sub
2 x 9 ½” Drill
Collars
2 x 9 ½” Drill
Collars
1 x 8 ¼”
Drill
Collars
25 7/8”
Roller Reamer
25 7/8” Roller
Reamer
Jet in BHA

21. 21
26” x 32 ½” BHA
Known Risks:
 Maintain Verticality
 Shallow water Flow
 Volume and Pressure
monitoring.
 Possible Fault
 Kick Potential
Discussion
Points
 Pre-Modeling
 Wellsite Prep
 Operation
 Contingencies
Wellbore Section
9 5/8”
SperryDrill
Lobe 6/7
-5 stg
NM Saver
Sub
32 ½”
DTU
AGR™
Collar
26” Tricone Bit
9 ½” EWR
M5™ Collar
W/DDSR
9 ½” PWD
22.5Ksi
9 ½” DM
Collar
9 ½” MPT
(Neg Pulser)
Float Sub with
Plunger type
float
Transition X-
Over 8” x 9”
Circulating
Sub
2 x 9 ½” Drill
Collars
2 x 9 ½” Drill
Collars
1 x 8 ¼”
Drill
Collars
25 7/8” Roller
Reamer
25 7/8” Roller
Reamer
26” x 32 ½”Hole Section Generic Example

22. 22
26” Hole Section Generic Example
Known Risks:
 Maintain Verticality
 Normal Down Dip Fault
 Volume and Pressure
monitoring.
 Kick Potential
Discussion Points
 Pre-Modeling
 Wellsite Prep
 Operation
 Contingencies
Wellbore Section
2 x 9 ½”
Drill
Collars
2 x 9 ½”
Drill
Collars
25 7/8”
Roller
Reamer
25 7/8”
Roller
Reamer
25 7/8”
Roller
Reamer
Transition X-
Over 8” x 9”
Circulatin
g Sub
NM Saver
Sub
AGR™
Collar
9 ½” EWR M5™
Collar W/DDSR
9 ½” PWD
22.5Ksi
9 ½” DM
Collar
9 ½” MPT
(Neg Pulser)
Float Sub with
Plunger type
float
9 5/8”
SperryDrill
Lobe 6/7 -5 stg
1 x 8 ¼”
Drill
Collars
Crossover
26” Tricone
26” BHA

23. 23
18 1/8”X 21” Hole Section Generic Example
Known Risks
 Possible gas cap
 High Total Gas
 Lost Circulation
 Hole Cleaning
 Entering top of salt
 Drillstring Dynamics
 Swab and Surge
18 1/8” x 21” BHA
(Top of salt expected in interval) Wellbore Section
18 1/8” PDC Bit
9 ½”
DrillDOC®
Geo Pilot
9600
18” Inline
Stabilizer
(ILS)
9 ½” EWR
M5™ Collar
W/ PWD
18” Inline
IB Stabilizer
9 ½” Sonic
Collar
9 ½” DM
Collar
18” Inline
IB Stabilizer
2 x 9 ½” Drill
Collars
1 x 9 ½”
Drill Collars
18” Roller
Reamer
18” Roller
Reamer
21” XR1800
Reamer
9 ½” MPT
(NEG PULSER)
Float Sub
w/Plunger Valve
1 x 9 ½”
Drill
Collars
Transitio
n X-
Over
Sub

24. 24
16 ½” x 17 ½” Hole Section Generic Example
16 ½” x 17 ½” BHA
(Base of salt expected in interval)
Wellbore Section
Known Risks
 High Total Gas
 Lost Circulation
 Hole Cleaning
 Drillstring Dynamics
 Stuck Drill Pipe in Salt
 Possible Inclusions
 Salt Creep
 Tar noted on offset
Discussion Points
 Pre-Modeling
 Wellsite Prep
 Operation
 Contingencies
16 ½”PDC
Bit
9 ½”
DrillDOC®
GeoPilot
9600
16 3/8” Inline
Stabilizer
(ILS)
9 ½” EWR
M5™
Collar
w/Gamma
Ray, PWD
16 3/8”
Inline
Stabilizer
(ILS)
9 ½” Sonic
Collar
9 ½”
Directional
Collar
17 ½”
XR1600
Reamer
9 ½” GeoTap®
25KSI
9 ½” MPT
(NEG
PULSER)
Float Sub
w/Plunger
Valve
1 x 9
½”Drill
Collars
1 x 9 ½”Drill
Collars
1 x 9
½”Drill
Collars
16 3/8”
Redback
Roller
Reamer
16 3/8”
Redback
Roller
Reamer
X-Over
Sub

25. 25
12 ¼” Hole Section Generic Example
Known Risks
 Pressure
uncertainty
 Ballooning
 Directional Build
 Fault uncertainty
 Fluid losses
Discussion
Points
 Pre-Modeling
 Wellsite Prep
 Operation
 Contingencies
12 ¼” BHA
Wellbore Section
12 ¼” PDC Bit
Geo-Pilot 9600
8” DrillDOC®
NM Saver
Sub
8” EWR-M5™
Collar
w/DDSR
8” ALD™
Collar
8” CTN™
Collar
8” NEG
Pulser
Float Sub
12 1/8”
Roller
Reamer
12 1/8” Roller
Reamer
8”
GEOTAP®
HF 30KSI
2 x 8 ¼”
Drill Collars
2 x 8 ¼”
Drill
Collars
8” Sonic
Collar
8” DM
Collar

26. 26
Evaluation and Reservoir Characterization
▌ The moment of truth
▌ Time to evaluate the rocks and fluids
▌ How big is the reservoir
▌ How much oil is in the reservoir
 Porosity
 Net sand
▌ How fast can you produce
 Permeability
 Pressure
 Viscosity
▌ What is the best way to produce it

27. 27
Completions
“Just because you drilled the well
does not mean you can complete it”
Ancient Proverb Completions Prophet

28. 28
Drivers Behind Completions in Deepwater
▌ Minimize Cost
 Reduce Installation Cost
 No Intervention Costs
▌ High Productivity
 Maximize Cash
Flow/Profitability
▌ Long Term Performance &
Reliability
 Minimize Economic Risk
 Minimize Workover
Costs/Op Ex
 Depletion Strategy

29. 29
Drilling versus Completions
▌ Drilling and completions need to work together to plan the wellbore
▌ Start from the reservoir
 What is the production rate
 What are the completion requirements
− What tubing is required for the production
− What casing size is required to accommodate the sand face
completion
▌ What completion equipment is required for the up hole completion
▌ Will the casing accommodate the completion
▌ Will the wellhead accommodate the completion

30. 30
Sand face Completions
▌ Horizontal (high angle) completions
 Cased and perforated completions
 Open hole completions
▌ Vertical completions
 Cased and perforated completions
 Open hole completions
▌ What is done in the “Golden Triangle”
 Gulf of Mexico
− Primarily cased and perforated Vertical completions
 Brazil
− Primarily open hole horizontal completions
 West Africa
− A combination of both vertical and horizontal completions

31. 31
Upper Completion
▌ Things to consider in the up-hole completion
 Blind space-out
 Selective or co-mingled production from stacked completions
 BHPT monitoring
 Tubing Retrievable Safety Valves
 Hydrate inhabitation
 Tubing hanger configuration

32. 32
Summary
▌ Know your Geology
▌ Know your Challenges and Risk
▌ Pre Plan and model
▌ Offset Data – Ensure it is correct and accurate – Must have!
▌ Monitor
▌ Prepare
“So much to know”

33. 33
Thank You!
Questions
David Mayhall
Drilling Engineering Solutions Manager
SPE Evangeline Section luncheon on May 19th Lafayette, Louisiana