Answer:
Conventional oil reserves are nearing depletion, and the remaining resources are predominantly found in challenging environments: high temperatures, high‑salinity formation waters, extreme reservoir heterogeneity, and high water cut – often exceeding 90%. These conditions push traditional chemical EOR methods to their technical limits. PDS was specifically developed to overcome these limitations, and its field‑proven operating envelope covers precisely the difficult settings that now dominate the global mature‑field portfolio.
| Parameter | PDS Operating Range | Why It Matters |
|---|---|---|
| Temperature | Up to 120 °C and beyond (tested) | The in‑situ flocculation mechanism remains stable at high temperatures where traditional polymers degrade or lose viscosity. Lab and field tests confirm performance at 120 °C, with potential for even higher conditions. |
| Salinity | Up to 250 g/L formation water | Field‑validated in the Kienqopskoe field at 250 g/L salinity. Unlike conventional polymers that precipitate or lose effect in high‑salinity brines, the PDS flocculation reaction is chemically robust and salinity‑tolerant. |
| Hardness | High Ca²⁺/Mg²⁺ tolerant | The dispersed particle system is insensitive to divalent cations that typically cause conventional polymer precipitation or viscosity loss. |
| Reservoir type | Sandstones, carbonates, fractured systems | Tunable floc size adapts to pore throats in sandstones and fracture apertures in carbonates – making the system lithology‑agnostic. |
| Permeability contrast | High heterogeneity and fracture networks | PDS is specifically designed for reservoirs where thief zones and high‑permeability streaks dominate flow. The residual resistance factor increases with permeability – the opposite of conventional polymer solutions. |
| Initial water cut | Successfully applied in wells with >90% water cut | High water cut is a direct symptom of the conformance problems PDS addresses. Treatments have repeatedly brought economically unviable, high‑water‑cut wells back into profitable production. |
This wide operating envelope is not accidental. It reflects the deliberate engineering of PDS to handle the very conditions that now characterise the world’s remaining oil resources: hotter, saltier, more heterogeneous, and more water‑cut than ever before. Whether the target is layered sandstones, fractured carbonates, or highly compartmentalised formations, if a reservoir has a conformance problem driven by permeability contrasts – regardless of temperature, salinity, hardness, or current water cut – PDS is a viable candidate, supported by ~2 000 well treatments across the Volga‑Ural region and Western Siberia.