Production-Otimisation-of-ESPs-in-Rumaila-Onshore-Iraq-BP-1

Production-Otimisation-of-ESPs-in-Rumaila-Onshore-Iraq-BP-1

2014 SPE European Artificial Lift Forum (EuALF)
Aberdeen, Scotland
17–18th June, 2014
Production optimization of ESP wells in Iraq
Rumaila oilfield
Presenter - Peter O. Oyewole, SPE,
BP
(Subsurface ESP Team Leader)
Presentation Objectives
•
To introduce Rumaila ESP application and the “unconventional”
optimization strategy, workflow process and case history
•
To share knowledge, lesson learnt and results (that might be valuable
for other operators)
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To obtain any feedback for further improvement
Content
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Introduction
•
ESP Optimization Challenge in Rumaila
•
ESP Optimization Strategy & Workflow Process
•
Constant Pressure Control Mode (PID loop)
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Case Histories & Examples
•
Results
•
The Future - Real Time Data Application on Rumaila ESP
•
Discussion, Questions & Comments
3
Rumaila Field
•
JV – (BP, CNPC, SOMO) =
Rumaila Operating
Organization in 2009
•
~ 1000 Wells (Active/Non-
Active Producer & Injectors)
4
Rumaila Field
• Simple Single Anticline
• 3 Main Reservoirs (Main Pay; Upper Shale; Mishrif)
• Early cretaceous deltaics system (series of stacked sandstone
interbedded the lower cretaceous carbonate System
• Field Area Coverage = 70km X 14km
• Rumaila/W.Qurna Structure --- >100Billion bbl STOIIP
5
Reservoir & Fluid
Properties
• “ESP Perfect
Application”
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6
High Rate (1-10mbd)
Low to No Solid Production
Low to Moderate GOR (400850 SCF/STB)
Oil Gravity (27-34 API)
Low Viscous Fluid (< 2cp)
Reservoir depth (22003300m)
Water Cut (0-60%)
Moderate (Mishrif) to High
Permeability(Main Pay)
ESP Current Overview
 Currently >230 mbd
(~20%) of Total
Field Production
 (25%) of Active
Producer Wells
 Growing # of ESP
and ESP Oil
Production
7
ESP Optimization & Operations Strategy
• High Range Operating Envelop (managing uncertainty)
– Operate in Downthrust (if required)
– No Upthrust
• Bias
-
Fully Open Choke (where applicable)
Low frequency operation
Low Motor Loading (50 -80%) – Motor Loading Range %
Managing Gas in Low PI wells – GS, AGH/GPU, HZ, Choke, Stages
Moderate Over-stage
ESP Optimization Challenge in Rumaila
• Flow Rate & Water Cut (WC) Measurement availability and frequency??
• Flow Rate & Water Cut Measurement Accuracy??
• Common Industrial Practice - Flow Rate & WC is known and use to
perform ESP Optimization and Intervention
• How do you perform ESP Optimization and Intervention without known
flow rate & WC?
• How will you understand well and ESP performance?
• How do you perform monitoring and troubleshooting?
• Additional requirement to provide accurate ESP well rate into Production
Allocation
ESP Optimization Strategy & Workflow Process
• Effective ESP Well Performance Modelling - Nodal Analysis
(SubPump & PROSPER)
• Flow Test & Fluid Sample Calibrated Models (subject to availability)
• Trouble shooting and understanding discrepancy
• Accurate Input Data
• Timely Data Acquisition (Weekly Update)
• Data Quantity Control
• Data Quality Control
• Perform Trend Analysis (Short Term & Long Term Trends)
• (See flow chart on the next slide)
ESP Monitoring & Optimization
Workflow Process
1. Weekly
Monitoring Field
Data
4. Data
Variation
Check
New WT Data & Wkly
OPS Monitoring Report
6. Run ESP
Performance
Model
5. ESP Optimization
Master Sheet
Update
Update of Daily
Entry/Ops report
(Wellwork)
2. Weekly Datalog
Download
3. Short
Term Trend
Analysis
OFM
Derived Rate &
Estim. WC
7. Yellow-Flag
Trouble Wells
 Vendor Field Ops
 Emerson data
8. Long
Term Trend
Analysis
11. ESP Well
Allocation
(SS Prod. Opt.)
Optimisation
Choke Change
Freq. Change
10. Weekly ESP
Summary
Report
PID Loop (Parameter Change)
9. Evaluation
& Analysis
(with Vendor)
Surveillance
WT Request
14. Update
Optimization
Tracking
(+ Gain/Loss)
13. Perform
Optimization
(Ops ESP
Coordinator)
12. Optimization
Request
(to Ops ESP
Coord.)
Sample Request
PBU Request
Yellow Flag Active Monitoring
Constant Pressure Control Mode (PID loop)
• ESP Wells VSD Control Modes - 3 Modes
• Value of Constant Pressure Control Mode in Rumaila ESP Application
– Managing BHFP near Saturation Pressure
– Maximize optimization gain
– Reduce wellsite visit and intervention (safety)
Function
Operating Value
High speed clamp
45 Hz
– Reduce human error
Low speed clamp
40 Hz
Target PIP
1900 PSI
Low threshold
1650 PSI
Proportional
3.00%
Derivative
0.00%
Integral
3.00%
THP (WHP)
220 PSI
Choke Setting Size
24
– Timely response to reservoir inflow performance
 Case 1 : Performance vs SOR estimation
SBHP
PI
WC
THP
Fr.
Intake Press
Flow rate
Motor Load
(psi)
(bpd/psi)
(%)
(psi)
(Hz)
(psi)
(bpd)
(%)
Expected case
3800
1.5
5
600
55
2072
2600
53
Stable Performance
3750
1.2
0
190
45
1900
1900
36
Case
Pump Curves (Design)
13
Pump Curves (Actual)
Case 1- PID Loop (Constant Pressure Mode)
THP/psig
FLP/psig
PIP/psi
Pd/psi
14
Constant
BHFP
Choke//64
Tm/℃
Freq./Hz
MA/amps
Case 2- Hole in Tubing
Case 3 – Pre & Post Optimization
PIP b4 Optz
PIP after Optz
Case 4- Decreasing PIP & Norm FG
Case 5- Increasing Norm. FG & WC
 Realtime data from RTU (Rumaila Future)
•
19
The Future - Real Time Data Application on Rumaila ESP
Before and after optimization (stable flow)
2012 ESP Optimization Skin
 12 MBD Annualized Rate
 52 Optimization Interventions
Questions
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Comments?
Feedback?
Input?
Discussion?
What else?
QUESTIONS
Acknowledgement
 Rumaila (ROO) ESP Subsurface & Operations team
 Rumaila (ROO) Subsurface Team Management
 BP