Drilling Fluid Additive

PHPA for Drilling Fluid — From Our Factory to Your Rig

We ship drilling-grade PHPA to rigs in Oman, UAE, Saudi Arabia, Brazil, Kazakhstan, and Indonesia. Last year alone, 3,000+ tons of our drilling polymer went to oilfields across 45 countries. The most common problem we solve? Operators using one PHPA grade for everything — viscosity, shale inhibition, and fluid loss — when each function needs a different molecular weight.

A horizontal well in Oman saved $180,000 by switching from oil-based mud to our KCl/PHPA system. Zero NPT from hole instability, versus 3 days on the offset well. Here is exactly what we recommended and why.

Three Functions, Three Grades

Viscosifier (15-25M MW)

At 1.0 kg/m³, our 18M PHPA increases apparent viscosity 3-8x. The shear-thinning behavior is what makes it superior to xanthan gum — low viscosity at the bit (fast ROP) and high viscosity in the annulus (cuttings transport). Above 90°C, xanthan degrades. Our PHPA holds to 120°C.

Shale Inhibitor (6-12M MW)

Reactive shales (montmorillonite, smectite) absorb water and swell — the #1 cause of NPT in drilling. Our 10M PHPA encapsulates shale cuttings and reduces osmotic water invasion. In reactive formations, PHPA-based muds reduce washout by 30-50% compared to untreated water-based muds.

Fluid Loss Reducer (8-15M MW)

Medium MW PHPA reduces API fluid loss from 15-25 mL/30min to 6-10 mL/30min. The filter cake is thin (1-2mm), tough, and easily removable — critical for production zones where you do not want permanent formation damage.

Temperature: The Critical Factor

Standard PHPA degrades above 120°C. For deeper wells (4,000-6,000m), we offer modified grades:

• <120°C: Standard PHPA (our 10M, 18M, 20M grades)
• 120-150°C: AMPS-modified PHPA ($2,500-3,000/MT)
• 150-180°C: AMPS/NVP terpolymer ($3,000-3,500/MT)

We test every high-temperature grade in an aging cell at actual bottomhole temperature for 24 hours. If viscosity drops more than 10%, we do not ship it.

Case Study: Oman Horizontal Well, 4,200m MD

The operator used our 10M PHPA at 2.0 kg/m³ for shale inhibition and 18M PHPA at 1.0 kg/m³ for viscosity. Bottomhole temperature was 115°C — standard grades worked fine. We shipped 5 tons of each grade with technical support via video call during the first circulation.

PHPA Water-Based Mud vs Oil-Based Mud

For wells below 120°C with moderate shale reactivity, PHPA water-based mud delivers 70-85% of OBM performance at 40-60% lower total cost. The environmental savings (no cuttings treatment) often tip the economics further.

Our Quality Control for Drilling Grades

Oilfield polymers demand tighter specs than general industrial grades. Our 3-tier QC:

1. In-process: Real-time polymerization temperature (±0.5°C), initiator ratio tracking
2. Batch testing: MW (±0.5M tolerance), solid content (≥92%), dissolution (≤90 min), residual monomer (≤0.05%)
3. Pre-shipment: Packaging integrity, moisture protection, container loading supervision

We retain samples from every batch for 24 months. If you have a field performance issue, we pull the retained sample and compare. Full traceability.

Pricing (2026, FOB China)

• PHPA viscosifier (15-25M MW): $1,800-2,200/MT
• PHPA shale inhibitor (6-12M MW): $1,500-1,800/MT
• AMPS-modified (high temp): $2,500-3,000/MT

MOQ: 500kg first order. Delivery: 7-10 days standard, 3-5 days urgent. We maintain buffer stock of popular drilling grades for emergency dispatch.

Frequently Asked Questions

Which grade do I need for my well?

Send us your mud program or offset well data — well depth, bottomhole temperature, formation type, current mud system. Our lab team recommends the optimal product within 24 hours. Not sure? We send free samples of 2-3 grades for your lab to test.

Powder or emulsion?

Powder is cheaper and has longer shelf life (2+ years). Emulsion hydrates faster (5-10 minutes vs 60-90 minutes for powder) — better for rig-site mixing where time is critical. Most operators use powder for planned wells and keep emulsion on standby for emergencies.

How do I handle high-salinity formations?

Standard PHPA tolerates up to 50,000 ppm TDS. Above that, polymer coils collapse and viscosity drops. For high-salinity wells, we offer salt-tolerant formulations (AMPS-modified) that maintain performance up to 200,000 ppm TDS. These cost 30-40% more but are essential for salt sections and high-TDS formations.