Chemical Qualification of Corrosion Inhibitors in the … › wp-content › uploads › 2020 › 02...
Transcript of Chemical Qualification of Corrosion Inhibitors in the … › wp-content › uploads › 2020 › 02...
“Quality, Integrity, Safety and Excellence”
Chemical Qualification of Corrosion Inhibitors in the Oil & Gas Industry: Impact of Test Approaches on Performance during Laboratory Screening
Electrochem 2019Technology Innovation Centre,
University of Strathclyde28th August 2019
Hunter ThomsonScaled Solutions Ltd.
Scaled Solutions
Internationally Recognised Independent Specialist Laboratory, Established 1999 • We specialise in Production Chemistry, Corrosion, Flow Assurance and Formation
Damage evaluation• Laboratory facilities in Livingston• International Client Base
• All Major operating companies • Chemical Vendors & Manufacturers
• Vision “Market leading partner globally for companies who need to solve challenges in relation to production chemistry, corrosion and formation damage”
• 2013 Opened First International Lab in Abu Dhabi • 2018 Office in Houston, USA – Lab in 2019
What We DoIn
tegr
ated
Production chemistry
Specialised field consultancy
Prediction, simulation and modelling
Scale control
Organic fouling
Corrosion control
Core flooding
Water injectivity and EOR
Analytical services – brine, oil, residuals and ESEM
Laboratory equipment manufacturing
1 to 1 R&D projects
Theoretical and practical training courses
Introduction• Maintaining integrity of oilfield equipment is essential to safe and efficient
production
• Controlled by system design & operations
- Many aspects required for control with chemical qualification at plausible worst-case conditions
• Qualifications usually involve screening a range of candidate chemicals
- An important aspect of accurate screening is the approach taken for each type of test as small changes could significantly impact outcome
- Parameters include, temperature, pressure, gases, hydrocarbon, wall shear stress, materials etc.
Background
• Typically use simplified, rapid tests to allow wide range of candidates
• Although simplified, conditions should be as representative of the field as possible - Which simplifications could lead to incorrect ranking?
• Here we examine how apparently small changes to these conditions can have significant impact on the outcome of chemical screening
Corrosion Inhibitor Qualification
• Cell contains fluid of interest
• 2 electrode set-up
– Same material as in the field
• Analysis by linear polarisation resistance (LPR)
– Open circuit potential measured
– Working electrode polarised and current density measured
– This can be used to calculate corrosion rate
Corrosion Inhibitor Qualification
CI FormulationsRange of corrosion inhibitors formulated, based on commonly used chemistries. Mosttests focussed on quaternary ammonium salt and phosphate ester.
All containing the same weight percentage of the respective active component,additives and solvents.
General performance investigated. Further tests focused on quaternary amine andphosphate ester.
Corrosion Inhibitor Qualification
• 50°C
• Ambient pressure
• 100% CO2
• 2 hours pre-corrosion
• pH 5.5
• Concentrations from 2.5 – 100 ppmv
Benchmark: achieve 0.1 mm/y within 2 hours of addition
Ion (mg/l)
Na+ 29358
Ca2+ 3145
Mg2+ 503
K+ 372
[SO4]2- 11
[HCO3]- 494
Synthetic Field Brine
Minimum Effective Dose (MED)Test Conditions
Minimum Effective Dose (MED)Results
Quaternary AmmoniumMED 10 ppmv
Phosphate Ester MED 25 ppmv
• 50°C
• Ambient pressure
• 100% CO2
• 0, 2, 4, 20 hours pre-corrosion
• 16 hours post inhibitor addition
• Quat at 10 & 20 ppmv
• pH 5.5
Ion (mg/l)
Na+ 29358
Ca2+ 3145
Mg2+ 503
K+ 372
[SO4]2- 11
[HCO3]- 494
Synthetic Field Brine
Effect of Pre-corrosionTest Conditions
Concentration: 10 ppmv
Active Component: Quaternary ammonium salt
Effect of Pre-corrosion
Effect of Pre-corrosion
Concentration: 20 ppmv
Active Component: Quaternary ammonium salt
• Maximum performance of the inhibitor appears to be achieved in tests withno pre-corrosion phase as a doubled dose rate results in a similar finalcorrosion rate
• At the higher CI concentration it can be seen that shortened pre-corrosionshows a clear trend of achieving a lower final corrosion rate
• 20 hour pre-corrosion tests see a borderline fail at (0.11 mm/y) improve to acomfortable pass (0.04 mm/y) by increasing the concentration
• Considerable time is required for 20 h pre-corrosion film formation (~5hr)compared to the shorter pre-corrosion tests (all < 1hr)
DiscussionEffect of Pre-corrosion
• 50°C
• 50% Watercut
• Ambient pressure
• 100% CO2
• 2 hours pre-corrosion
• 16 hours post inhibitor addition
• Quat at 10 ppmv
• Phosphate ester at 25 ppmv
• pH 5.5
Ion (mg/l)
Na+ 29358
Ca2+ 3145
Mg2+ 503
K+ 372
[SO4]2- 11
[HCO3]- 494
Synthetic Field Brine
Test ConditionsDual-phase Dosing Methods
Brine
Oil
CI
CI
Oil added after CI mixed into oil
CI
CI
Method 1 Method 2 Method 3
Oil added after CI mixed into brine
Method 4
Dual-phase Dosing Methods
Concentration: 10 ppmv
Active Component: Quaternary ammonium salt
Dual-phase Dosing Methods
Dual-phase Dosing Methods
Dual-phase Dosing Methods
Concentration: 25 ppmv
Active Component: Phosphate Ester
• Overall both inhibitors reduce the final corrosion rate to below 0.1 mm/yregardless of dosing method
• Summary of results:
• In this case, ranking of these inhibitors changes depending on dosingmethod used
Addition MethodFinal Corrosion Rate (mm/y)
Quat Phosphate Ester
100% Brine 0.02 0.03
1 0.02 0.04
2 0.02 0.05
3 0.07 0.04
4 0.02 0.04
Dual-phase Dosing MethodsDiscussion
• 50°C
• 50% Watercut
• Ambient pressure
• 100% CO2
• 1, 2, 4 & 20 hour pre-partitioning
• 16 hours post inhibitor addition
• Quat and phosphate ester at MED
• pH 5.5
Ion (mg/l)
Na+ 29358
Ca2+ 3145
Mg2+ 503
K+ 372
[SO4]2- 11
[HCO3]- 494
Synthetic Field Brine
Pre-partitioning DurationTest Conditions
Pre-partitioning Duration
Concentration: 10 ppmv
Active Component: Quaternary ammonium salt
Longer pre-partitioning increases final rate
Pre-partitioning Duration
Pre-partitioning duration Wet Chemical CI Assay(ppmv)
1 10.3
2 8.3
4 7.4
20 7.1
Longer pre-partitioning decreases final rate
Pre-partitioning Duration
Concentration: 25 ppmv
Active Component: Phosphate Ester
• Testing of Quat showed the longer the time allowed for pre-partitioning, the lowerthe availability of CI in the brine phase
• The availability of CI is shown in assay results table below which shows a moresignificant change from 1 to 4 hours than from 4 to 20 hours.
• The similarity between 4 and 20 hour pre-partitioning results suggest an equilibriumhas been reached
• The phosphate ester showed the opposite trend with lower corrosion rates at longerpre-partitioning times.
Pre-Partition Time (h)Corrosion Rate at 2h
(mm/y)Final Corrosion (mm/y)
Wet Chemical
CI Assay (ppmv)
1 0.03 0.03 10.27
2 0.03 0.02 8.17
4 0.05 0.06 7.41
20 0.05 0.05 7.14
Pre-partitioning DurationDiscussion
Pre-partitioning Duration
Pre-partitioningduration (hours)
Final Corrosion Rate (mm/y)
Quat Phosphate Ester
1 0.03 0.04
2 0.02 0.03
4 0.06 0.03
20 0.05 0.02
• Ranking of inhibitor might depend on pre-partitioning duration
• This will depend on the particular chemistries or formulations involved
Test Conditions
• 90°C
• Field: 2.5 bar CO2
• Saturation Ratio < 1
• Lab: Ambient pressure, 100% CO2
• Saturation Ratio = 4.6
• 2 hours pre-corrosion
• 16 hours post inhibitor addition
• Quat at 5 ppmv
Ion (mg/l)Na+ 32000Ca2+ 5800Mg2+ 1600
K+ 360[SO4]2- 1800[HCO3]- 260
Scaling Field Brine
Self Scaling Brine Systems
Brine Composition [Ca2+] [Sr2+] [HCO3-] [SO4
2-]
Unadjusted 5800 360 260 1800
Anions Removed 5800 360 0 0
Anions Reduced 5800 360 150 450
Reduced [HCO3]- 5800 360 150 1800
Reduced [SO4]2- 5800 360 260 450
Ca Removed 0 360 260 1800
Sr Removed 5800 0 260 1800
Reduced Ca 1000 360 260 1800
Reduced Sr 5800 40 260 1800
Brine Composition [Ca2+] [Sr2+] [HCO3-] [SO4
2-]
Unadjusted 5800 360 260 1800
Anions Removed 5800 360 0 0
Anions Reduced 5800 360 150 450
Reduced [HCO3]- 5800 360 150 1800
Reduced [SO4]2- 5800 360 260 450
Ca Removed 0 360 260 1800
Sr Removed 5800 0 260 1800
Reduced Ca 1000 360 260 1800
Reduced Sr 5800 40 260 1800
Scaling Field Brine Composition AdjustmentsSelf Scaling Brine Systems
• Various options to control in tests – reducing / removing scaling ions, or adding scale inhibitor
• Higher pH and scaling tendency of the field brine under ambient pressure conditions could lead to a milder condition than that experienced in the field
Brine Composition [Ca2+] [HCO3-] pH Saturation Ratio
Field 5800 260 5.2 <1
Unadjusted lab 5800 260 5.6 4.6
Reduced [Ca2+] 1000 260 5.7 0.9
Reduced [HCO3-] 5800 150 5.3 1.6
Self Scaling Brine Systems
Self Scaling Brine Systems
Concentration: 5 ppmv
Active Component: Quaternary ammonium salt
Scaling of blank
Mitigated scaling of blank
Significant difference between unadjusted and scale controlled brines – in this case straddling the pass criterion
Self Scaling Brine Systems
• Apparent minor adjustments to the way tests are conducted can havesignificant effect on CI performance
• This can lead to a significantly different outcome for a CI screening study
- Potentially changing ranking and selection of inhibitors
• It is key to select appropriate conditions
- These should be as representative as practicable, and whereparameters are uncertain, be prudently conservative
Conclusions
Thank you for your time
Contacts:
Other enquiries: [email protected]
Dr Ian Carpenter, Corrosion Team Leader: [email protected]
Dr Paul Hammonds, R&D Manager: [email protected]