the development of a downhole corrosion sensor for
TRANSCRIPT
MCE Deepwater Development 2016
PAU, FRANCE • 5-7 APRIL 2016
The Development of a Downhole
Corrosion Sensor for Condition
Monitoring of Electrical Submersible
Pumps
Dr. Tom Elson, Stewart Barlow, Dan Clarke - Teledyne Oil & Gas
Ashwin Chandran - Baker Hughes
MCE Deepwater Development 2016
1. Impact of Corrosion 2. Problem Statement 3. ESP System Overview 4. Corrosion Measurement Principle 5. Corrosion Sensor Overview 6. Sensor Design 7. Sensor Testing 8. Conclusions & Next Steps
Content
MCE Deepwater Development 2016
Corrosion in Electrical Submersible Pumps (ESP)
• Typical corrosion types on ESP equipment • Galvanic
• Pitting
• Microbiologically influenced corrosion
• Sulfide stress corrosion cracking
• Water injection and sea water applications
• Graphite corrosion
• Stress corrosion cracking
• Crevice corrosion Cr 13% corroded –
seawater application Monel shaft
corroded
(seawater
application)
MCE Deepwater Development 2016
Corrosion Factors and Mitigation
• Exotic corrosion-resistant alloys • Expensive
• Corrosion-resistant coatings • Cannot be used everywhere
• Not very effective at higher temperatures
• Chemical Treatment - Corrosion Inhibitors • Blind injection of a predetermined
quantity
• Cannot measure effectiveness
• Factors affecting downhole corrosion
• Gas composition and quantity
• Water
• pH
• Pressure (Partial pressure)
• Temperature
• Flow velocity and Pattern
• Fluid / oil type
MCE Deepwater Development 2016
Problem Statement Opportunity:
• ESP failures due to corrosion is a real problem, resulting in costly workovers.
• Chemical treatment needs feedback to be more effective.
Gaps:
• Surface corrosion measurements are a lagging indicator; no downhole monitoring of corrosion.
Approach:
• Develop a downhole corrosion sensor capable of measuring 1 mpy in 24 hr.
• Proven technology of electrical resistance monitoring to detect metal loss.
Impact:
• Immediate action on corrosion rate change
• Optimized injection - reducing chemical cost
• Minimal work-over cost due to corrosion failure
• Total customer annual cost expected to be reduced by 10%
MCE Deepwater Development 2016
ESP System Overview
• Existing Baker Hughes downhole platform was used for power and communications
• Corrosion sensor interfaces mechanically and electrically with existing WellLift-N gauge
• Interface is pressure sealed with electrical
feed-throughs • Existing firmware was modified to accept
and transmit data from the Corrosion sensor
S R
WL-N
MCE Deepwater Development 2016
Sensor Design Requirements
• Three prototypes designed and built in 2015 as technology demonstrators to meet the following key requirements:
Environmental Requirements
Pressure & Temperature Rating 5 kpsi, 80 °C
Shock Resistance 100g
Measurement Performance
Metal Loss Range 0 to 5mm
Sensitivity 1 mpy detection in 24 hours
Maximum Package Size
Diameter < 3.375 in.
Length < 12 in.
Electrical Interface
Power Consumption <1W
Communication Online digital every 4 seconds
MCE Deepwater Development 2016
Corrosion Measurement Principle: Electrical Resistance
Patented CEION© technology used to achieve high-resolution measurement of extremely small resistances ≈mΩ
MCE Deepwater Development 2016
Corrosion Sensor Overview
Interface to centraliser
Interface to MGU Electronics
Housing
Reference Element Protective Shroud
Sample Element
Sample Element
Reference Element
MCE Deepwater Development 2016
Sensor Design Analysis
Computational Fluid Dynamics Used to ensure that the flow over the sensor element is uniform and representative.
Finite Element Analysis Used to ensure mechanical integrity of the housing under pressure and other loads.
MCE Deepwater Development 2016
Sensor Qualification Testing
Shock & Vibration (ISO13682-6) • 8 x 100g shocks on all axes • 25 – 1000 Hz vibration sweeps at 5g on
all axes • 2 hour random endurance test at 6g rms
Preliminary Reliability Testing • PCBs (4off) soaked at 95°C
for 3 months
Thermal Testing • Thermal endurance: 90°C for 7 days • Thermal cycling: 65 to 80°C 24 times
at 5°C per minute.
MCE Deepwater Development 2016
Sensor Performance Test
• Tested in brine under in a sealed environment • Tested under low (N2) and high (CO2) corrosion • LPR measurement used as a reference • Corrosion rates calculated over a 6 hr window • Good agreement with reference rate
MCE Deepwater Development 2016
Sensor Performance Test
Cumulative Metal Loss has been post-processed to determine Metal Loss Rate, using a Least Square Fit approach.
Target Achieved
Resolution (nm) 70 30
Time to observe 1 mpy (hours)
24 10
Measurement range (mm) 5
5
MCE Deepwater Development 2016
Conclusions & Next Steps
• Successful technology demonstrator for Downhole Corrosion Sensor for ESP condition monitoring by Baker Hughes and Teledyne-Cormon.
• Initial prototypes has successfully completed qualification awaiting field trial.
• Initial performance testing is encouraging with clear corrosion trends evident over short periods of time (<6 hours).
• Integration tests with WellLift-N on an ESP with existing surface equipment is complete and prototype sensors are ready for in well field trial
MCE Deepwater Development 2016
Name Email
Tom Elson [email protected]
Dan Clarke [email protected]
Stewart Barlow [email protected]
Ashwin Chandran [email protected]
Author Contact Information