CASE STUDIES
SOLUTIONS
IRON CONTROL + WATER CONDITIONER
SCi7775 is a powerful anti-foulant chelation chemistry with solvency, surfactancy, and demulsification properties.
It is designed to chelate Iron in high-salinity Calcium-based brines. SCi7775 is currently being applied to treat foulant laden emulsions in Montney wet gas production.
COST REDUCTION
Per day/on average
REDUCTION IN TRUCKING VOLUMES
Continuous injection compared to intermittent injection
%
AVERAGE REDUCTION IN FILTER CHANGES
12 months
%
SCi7775
Iron Control Scale Inhibitor + Water-Flood Conditioner
SCi7775 is a powerful anti-foulant chemistry which uses a blend of high-performance additives to achieve scale control in oilfield systems. It also acts as a high activity chelant, which effectively inhibits iron cations in the presence of Calcium and high TDS brines.
SCi7775 is capable of both retarding the formation of Iron Sulfides and removing Iron Sulfide deposits over time. It has water wetting capacities for removing oil filming and keeping scaling cations soluble in mixed pH regimes.
To treat problems associate with Montney wet gas production, the SCi7775 excels due to its solvency, surfactancy, and demulsification properties.
De450w
Anti-Foulant + Demulsifier/Desludging Agent
De450w breaks flow back foulant laden emulsions and acid oil emulsions. It is water soluble, but its components can partition into the oil phase to effectively break out foulants, solids and asphaltenes which tend to stabilize emulsions.
DE450w effectively reduces the interfacial tension and changes the wetting of solids to break emulsions and cause foulants to drop into the interface and the brine.
CD235i Case Study
Verdechem Technologies has built a very effective solvent/dispersant for the Kakwa/Montney formation.
History
An E&P company has been experiencing major internal fouling and plugging from newly fracked wells. Internal issues caused floats and valves to stick open flooding condensate to water tanks and carrying over water to condensate sales bullets. This resulted in huge trucking costs, down time, and lost production. The E&P company had several solvent programs currently running but the products were ineffective.
Field Testing
Samples of the paraffin were collected from the
field and testing was completed. VerdeChem Technologies developed a surfactant-based solvent with crystal modifiers that demonstrated a significant improvement in overall performance compared to previous chemistries used.
The following pictures show the main difference in solvency vs. inhibition. Please note that inhibition is not an application of the CD235i itself.
In the pictures to the right, you can quickly see the importance of proper solvency selection in developing a product that will quickly solvate or disperse the paraffin from reforming.
Recommendations
VerdeChem recommended that we set up mobile units on the newly fracked well pads to inject CD235i into the flow line to the effected Pad Separator to alleviate the problem.
Conclusion
Within a couple of hours, the Pad that was experiencing these problems was quickly cleaned up and running normally. This is now a regular program with newly fracked wells.
MS306Bpp
INHIBITION CASE STUDY
MS306Bpp is a solvent-based, oil soluble chemical formulation for use in crude oil and condensate to control paraffin deposition. It is also a wax crystal modifier/pour point depressant that inhibits the gelation of the oil. The MS306Bpp is winterized and optimized for continuous injection in process facilities and downhole applications.
There was a flow assurance issue where condensate stabilizers were swinging – the stabilizer was reading high levels due to foulant buildup on the stage valves. VerdeChem field trialed the MS306Bpp to solve the problem. Chemical injection was started at the feed drum that carries over into the reboiler and stabilizer tower.
Below is a before and after comparison of the Stage Valves pre and post injection:
SOLUTIONS IN DEVELOPMENT
16-36 Cadotte Injection Well
This injection well was completed in the Cadotte sandstone formation. This formation is often calcareous with iron bearing authigenic mineralogy like siderite and glauconite. Prior to conducting the Verdechem diverted acid stimulations, before March 2015, all prior acid stimulation attempts provided a couple months of incremental injection. Kik Lite acid stimulations, with rock salt diversion and most recently without diversion, have consistently provided much higher and longer incremental injection cycles: resulting in appreciable stimulation cost savings as well as improved reservoir pressure support. The most recent acid stimulations have been weighted with additional specialized solvents to deal with increased amounts of oil carry-over.
Iron Sulfide & Elemental Sulfur precipitation
Mixing sour high TDS Montney brine with downhole connate sweet Paddy brines (containing natural Iron cations) may result in the formation of hydrocarbon coated hydrophobic iron sulfide and/or elemental sulfur precipitates. These precipitates can potentially plug the porosity and permeability of an intended disposal reservoir; causing a rapid increase in injection pressures and commensurate reduction in injection rates.
Verdechem Technologies has developed proprietary anti-foulant chemistries which combine effective Iron Control with acid buffering and water wetting effects to mitigate the formation of damaging precipitates.
We are currently conducting a field trial with a leading E&P Company in the Grand Prairie Region to verify the efficacy of employing these types of anti-foulant chemistries to control and minimize the damaging effects of Iron Sulfide and Elemental Sulfur precipitation when mixing sour Montney brine with incompatible connate fluids.
Mixing of Sour 16-21 Montney Brine & 06-07 Paddy Brine (80:20) + 50 ppm of Ferric Iron
SCi5000 – 400 ppm + Sulfamic Acid (10%) + 1 % HCl – 1,000 ppm (Best Performance)
Far Left: Mixed Brine Blank 80:20 Blend 50 ppm Fe+3 Spike.
Middle: Mixed Brine Treated SCi5000 – 400 ppm Sulfamic Acid (10 %) – 1,000 ppm.
Far Right: Mixed Brine Treated SCi5000 – 400 ppm Sulfamic Acid (10 %) + 1 % HCl