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Preliminary Suggestions
| Typical indicators / objective observations | Likely direct causes | Low-cost actions to try first | When you should introduce / re-select PAM | Why PAM is recommended here |
|---|---|---|---|---|
| Injected viscosity too low | MW window too low; incomplete hydration; salinity reduces performance | Improve hydration SOP; validate in representative brine; standardize mixing energy and time | When mobility control is required for sweep improvement | High-MW PAM increases viscosity and improves mobility ratio |
| Viscosity degrades after mixing or over time | Shear degradation; temperature sensitivity; incompatibility | Reduce shear in pumps/valves; validate stability over time and temperature | When viscosity retention is required for field performance | Correct selection balances performance strength with shear tolerance |
| Injection pressure rises (plugging concern) | Incompatibility/precipitation; poor filtration; too high concentration | Run compatibility and filtration tests; optimize concentration and filtration | When injectivity protection is critical | Compatibility-first selection reduces precipitation and plugging risk |
Applicability boundary: Applicable for polymer flooding programs where viscosity and compatibility are key. If injectivity issues are dominated by formation damage unrelated to polymer (scale, fines, biofouling), address those factors in parallel.
Selection guidance: how to choose the right polymer program for this oilfield scenario
Molecular weight (MW): performance strength vs. shear sensitivity
MW influences friction reduction, viscosity build, and overall fluid behavior. Higher MW can strengthen performance but can be more shear-sensitive. Select MW based on pump rate, shear environment, and your blending constraints.
Ionicity and compatibility: brines, additives, and formation minerals
Ionic type affects compatibility with salts, surfactants, breakers, and formation minerals (especially clays). A compatibility-first approach reduces precipitation risk, residue risk, and performance loss.
Emulsion vs powder: hydration speed and operational tempo
Powder requires disciplined hydration and sufficient mixing time; emulsion is often used when faster hydration and rapid response are needed. Choose based on blending equipment, water quality, and the operational tempo on location.
Multi-additive systems: validate the full fluid, not a single component
Oilfield fluids are multi-additive systems. Selection should be validated through controlled compatibility and performance tests at representative salinity and temperature.
Initial recommendation
Starting point: Start with a brine-compatibility selection: validate hydration and viscosity build in representative brine, then tune MW for target viscosity while confirming shear stability and injectivity safety.
Contact us for a precise grade recommendation
A precise recommendation requires your operating parameters. Please submit the form and include the items below (ranges/estimates are acceptable). We also welcome complex or rare cases.
- Reservoir brine composition and salinity/hardness: Controls polymer hydration and viscosity response.
- Target viscosity at injection conditions: Defines the performance target and acceptance criteria.
- Temperature and shear exposure in facilities: Affects viscosity retention and degradation risk.
- Filtration and injectivity constraints: Ensures the program is safe for injection and avoids plugging.
- Make-up water source variability: Explains batch-to-batch response changes.
- Problem repeat probability: Guides robustness needs for long-term programs.
What you will receive: recommended type/form, 2–3 candidate grade windows, an initial dosage guidance for a controlled field trial, and step-by-step mixing/compatibility test suggestions.
