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

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

Industry standards and practices that promote reliability

and safety through the use of proven engineering

practices

4

The Deep-water Area Covered in Todays Presentation

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

Quickly Understand the Big Picture

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

Alaminos Canyon

9

Keathley Canyon

10

Walker Ridge

11

Green Canyon & Atwater Valley

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

Deep Water Challenges

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

© 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

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

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

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

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

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

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

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

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

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

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

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

Completions

“Just because you drilled the well

does not mean you can complete it” Ancient Proverb Completions Prophet

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

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

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

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

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

Thank You!

Questions

David Mayhall

Drilling Engineering Solutions Manager

SPE Evangeline Section luncheon on May 19th Lafayette, Louisiana