esp technology challenges for ultra-deepwater in gulf … · esp technology challenges for...
TRANSCRIPT
1
© 2
014
Bak
er H
ughe
s In
corp
orat
ed. A
ll R
ight
s
Res
erve
d.
© 2014 BAKER HUGHES INCORPORATED. ALL RIGHTS RESERVED. TERMS AND CONDITIONS OF USE: BY ACCEPTING THIS DOCUMENT, THE RECIPIENT AGREES THAT THE DOCUMENT TOGETHER WITH ALL INFORMATION INCLUDED THEREIN IS THE
CONFIDENTIAL AND PROPRIETARY PROPERTY OF BAKER HUGHES INCORPORATED AND INCLUDES VALUABLE TRADE SECRETS AND/OR PROPRIETARY INF ORMATION OF BAKER HUGHES (COLLECTIVELY " INFORMATION"). BAKER HUGHES RETAINS ALL RIGHTS
UNDER COPYRIGHT LAWS AND TRADE SECRET LAWS OF THE UNITED STATES OF AMERICA AND OTHER COUNTRIES. THE RECIPIENT FURTHER AGREES TH AT THE DOCUMENT MAY NOT BE DISTRIBUTED, TRANSMITTED, COPIED OR REPRODUCED IN WHOLE OR
IN PART BY ANY MEANS, ELECTRONIC, MECHANICAL, OR OTHERWISE, WITHOUT THE EXPRESS PRIOR WRITTEN CONSENT OF BAKER HUGHES, AND MA Y NOT BE USED DIRECTLY OR INDIRECTLY IN ANY WAY DETRIMENTAL TO BAKER HUGHES’ INTEREST.
ESP Technology Challenges for
Ultra-Deepwater in Gulf of Mexico
Author: Carlos Lopez
Sr. Application Engineer C&P GOM
EuALF 2014
2
© 2
014
Bak
er H
ughe
s In
corp
orat
ed. A
ll R
ight
s
Res
erve
d.
Agenda
• Lower Tertiary Trend Overview
• Reservoir Characteristics
• Objectives & Methodology
• Results Analysis
• ESP Completion Options
• Summary
3
© 2
014
Bak
er H
ughe
s In
corp
orat
ed. A
ll R
ight
s
Res
erve
d.
The Value Proposition - Lower Tertiary Trend GOM
• Lower Tertiary is thought to contain
15 billion barrels of oil in reserves
• Current known extent is approx.
80 mi wide and 400 mi long
• LT consists of older geological
period, more compact sediments
• High density crude with low GOR
and bubble point
• Highly fractured reservoirs – rapid
pressure depletion
• Reservoir pressure to 20,000 psi,
Temperature to 300º F
4
© 2
014
Bak
er H
ughe
s In
corp
orat
ed. A
ll R
ight
s
Res
erve
d.
Regional Discontinuity
12,000
35,000
20,000
24,000
Major depth shift across discontinuity
Walker Ridge
EPOCH TIME SCALE
2 MM Years Ago
5 MM Years Ago
OLIGOCENE
34 MM Years Ago
EOCENE
PALEOCENE
65 MM Years Ago
PERIOD
PLIOCENE
T
E
R
T
I
A
R
Y
P
A
L
E
O
G
E
N
E
N
E
O
G
E
N
E
MIOCENE TREND
LOWER TERTIARY TREND
Graph courtesy MMS
5
© 2
014
Bak
er H
ughe
s In
corp
orat
ed. A
ll R
ight
s
Res
erve
d.
Objectives
• Model anticipated Lower Tertiary reservoir to evaluate
production potential
• Compare the production expectations to understand the
economic viability of ESP completion design options
• Evaluate ESP challenges to meet the completion needs
of Lower Tertiary wells
6
© 2
014
Bak
er H
ughe
s In
corp
orat
ed. A
ll R
ight
s
Res
erve
d.
Methodology
• Nodal Analysis - Petroleum Experts Prosper® Software
• ESP Production Modeling - Baker Hughes’ AutographPC®
• Compare various reservoir performance characteristics
7
© 2
014
Bak
er H
ughe
s In
corp
orat
ed. A
ll R
ight
s
Res
erve
d.
Natural Flow Scenario
PRODUCER WELL
FACILITIY
• No Subsea Boosting
• No In-Well ESP
• 250 psi Separator Pressure
• Step out 14 Miles
• Water depth 8,000 ft
• Flowline ID 6”
• Productivity Index (PI) of 1.0 to 3.0 bpd/psi
8
© 2
014
Bak
er H
ughe
s In
corp
orat
ed. A
ll R
ight
s
Res
erve
d.
Subsea Booster Pump Scenario
PRODUCER WELLS
SUBSEA
BOOSTER
PUMP
• Subsea Boosting
• No In-Well ESP
• 1,250 psi Min. Subsea Tree Pressure
• PI = 1.0 to 3.0 bpd/psi
9
© 2
014
Bak
er H
ughe
s In
corp
orat
ed. A
ll R
ight
s
Res
erve
d.
Combined Artificial Lift Scenario
© 2009 Baker Hughes Incorporated. All Rights Reserved. 9
IN-WELL ESP
SUBSEA
BOOSTER
PUMP
`
• Near-Reservoir ESP, maximizing reservoir drawdown
• Subsea Boosting
• 1,250 psi Min. Subsea Tree Pressure
• 1,250 psi minimum Pump Intake Pressure
• PI of 1.0 to 3.0 bpd/psi
10
© 2
014
Bak
er H
ughe
s In
corp
orat
ed. A
ll R
ight
s
Res
erve
d.
Water Depth ft
Reservoir Depth (TVD) ft
Reservoir Temperature ºF
Initial Reservoir Pressure psi
Water cut %
Permeability md
Productivity Index bpd/psi
Oil Viscosity cP
Oil API gravity ºAPI
Bubble point Pressure psi
Gas Oil ratio (GOR) scft/sbbl 250
20,000
1.0 - 3.0
28
1,250
30
8,000
28,000
275
3
10
Reservoir Characteristics
11
© 2
014
Bak
er H
ughe
s In
corp
orat
ed. A
ll R
ight
s
Res
erve
d.
In-Well ESP Natural Flow
Subsea Booster Pump
Production Profile PI=3 bpd/psi
Drawdown limited to 5,000 psi
0 bpd
5,200 bpd @ 6,000 psi
0 bpd
12
© 2
014
Bak
er H
ughe
s In
corp
orat
ed. A
ll R
ight
s
Res
erve
d.
In-Well ESP Natural Flow Subsea Booster Pump
Production Profile PI=2 bpd/psi
Drawdown limited to 5,000 psi
0 bpd
3,500 bpd @ 6,000 psi
0 bpd
13
© 2
014
Bak
er H
ughe
s In
corp
orat
ed. A
ll R
ight
s
Res
erve
d.
In-Well ESP Natural Flow Subsea Booster
Pump
Production Profile PI=1 bpd/psi
Drawdown limited to 5,000 psi
0 bpd
1,800 bpd @ 6,000 psi
0 bpd
14
© 2
014
Bak
er H
ughe
s In
corp
orat
ed. A
ll R
ight
s
Res
erve
d.
ESP Pump Performance
PI 2 bpd/psi PI 1 bpd/psi
15
© 2
014
Bak
er H
ughe
s In
corp
orat
ed. A
ll R
ight
s
Res
erve
d.
ESP Completion Options
• Deployment Multiple ESP Systems to Maximize Time Between Interventions
– Design Completion to avoid interventions for at least 8 to 10 years
– Use Conventional Drilling Rig Intervention with a Riser
• Coiled Tubing Deployed ESP System to Minimize Time and Cost for an
Intervention
– Design Completion to keep Intervention Time at 30 Days or less
– Use Emerging Medium Intervention Vessel Technology
16
© 2
014
Bak
er H
ughe
s In
corp
orat
ed. A
ll R
ight
s
Res
erve
d.
Deployment Multiple ESP Systems
Challenges
`
• Production casing larger than standard GOM
• ESP CAN/Pod must be large
• Tubing hanger design
• Subsea Tree ESP power penetrator design
• CAN/Pod hanger design for high pressure
• ESP CAN power penetrator design
• Automatic diverter valve design for high volume
• ESP pump design for widest production range
• ESP qualification for extremely high pressure
• High pressure completion components:
– Safety Valve
– Reservoir isolation Barrier valve
– Chemical Injection system
17
© 2
014
Bak
er H
ughe
s In
corp
orat
ed. A
ll R
ight
s
Res
erve
d.
Coiled Tubing Deployed ESP System
Challenges
• Coiled Tubing Hanger design
• Production Tubing Hanger design
• SubseaTree ESP power penetrator
• CT with Power Cable technology limits to 10,000 ft
• CT collapse pressure limitations
• ESP pump design for widest production range
• ESP qualification for extremely high pressure
• Length and weight of the ESP system
• Coiled tubing size
• Bypass Valve Design
• High pressure completion components:
– Deepset Safety Valve
– Reservoir isolation Barrier valve
– Chemical Injection system
18
© 2
014
Bak
er H
ughe
s In
corp
orat
ed. A
ll R
ight
s
Res
erve
d.
Summary
• Available reserves will keep the GoM as one of the world’s premier oil and gas basins
for the oil industry
• Sensitivity analyses for LTT shows that potential oil increase per well would be more
than 50% over the life of the field by adding an ESP along with the SSB system
• Deployment of multiple ESP systems is the conventional approach which has
previous and successful run history. The current technology should be adapted to this
application
• CT deployed ESP systems in subsea and deepwater applications would be
challenging and development of the components would require extensive engineering
time, testing and qualification
19
© 2
014
Bak
er H
ughe
s In
corp
orat
ed. A
ll R
ight
s
Res
erve
d.
Acknowledgements
Andres Cardona Applications Engineering Advisor
Baker Hughes, Gulf of Mexico Region
Raymond O’Quinn Project Manager
Baker Hughes, Gulf of Mexico Region
20
© 2
014
Bak
er H
ughe
s In
corp
orat
ed. A
ll R
ight
s
Res
erve
d.
Questions
Carlos Lopez Baker Hughes, Gulf of Mexico