A game-changing, hydrogen-driven well stimulation technology — delivering gains of up to 2,000%, without hydraulic fracturing or special equipment.
Conventional stimulation often means one problem, one technology, one intervention.
But decline in well productivity is rarely caused by a single mechanism. Low permeability, formation damage, skin, blocked pore space, fines, heavy hydrocarbon deposits, condensate banking, perforation damage, residual treatment fluids, and the aftereffects of unsuccessful prior interventions, etc., can act simultaneously — restricting flow and limiting the effectiveness of individual treatments.
Addressing these problems separately can mean multiple interventions, specialized equipment, downtime, higher costs and limited treatment scope.
It treats the productive formation as an interconnected system, integrating thermal, chemical, physical and mechanical effects within one precisely controlled, sequential Chemical-Technology Process (CTP).
Every well is unique — so the Chemical-Technology Process is adapted individually every time, to its specific geological, technical and other characteristics, for maximum results.
Each stage is engineered to prepare, enhance and reinforce the next — creating one coordinated stimulation effect instead of a series of isolated interventions.
HYDROSTIM is engineered for highly controlled, precisely directed impact on the productive formation, preserving well integrity, near-wellbore stability and equipment safety while minimizing environmental impact.
Its integrated action is designed to restore flow capacity, enhance permeability, remove multiple types of formation damage and create new pathways for hydrocarbon flow.
One integrated, field-proven treatment instead of multiple less effective separate interventions. Standard workover equipment instead of a specialized fleet. Higher production — compared to conventional methods. Lower operational complexity. Fast payback. An effect capable of lasting years, not months.
The simultaneous, integrated action of four mechanisms:
+Thermal+Chemical+Physical+Mechanicaleliminates every cause of productivity decline in a single treatment operation.
+Precisely engineered chemical-technological process (CTP)+Targeted formation impact
+Well integrity — surface and downhole equipment+Formation stability+Environmental care+Minimal CO₂ emissions
+Higher production potential+Fewer interventions+Sustainable economic value
Well history, geophysics and core-laboratory studies under simulated thermobaric conditions define the target zone.
Components A and B are formulated for your reservoir chemistry, depth and completion type.
Pumped with a standard workover rig or coiled tubing. At the bottomhole the reaction releases heat, activated hydrogen and a controlled acid–alkali–acid cycle — while engineered micro-fracturing opens new flow paths, without a single macro-fracture.
100–350 °CThe well is shut in for 12–24 hours while a neutraliser stops the reaction and generates natural surfactants that keep the new channels clean. The well is then brought back on production — effect lasts from 12 months to 6+ years.
PAYBACK 1–3 MONTHS
HYDROSTIM is a patented Enhanced Oil Recovery (EOR) and well stimulation technology developed by IPT Company in exclusive partnership with the A.M. Pidgornyi Institute of Power Machines and Systems of the National Academy of Sciences of Ukraine.
Most wells underperform not because the reservoir is depleted, but because the pathway to it is blocked.
HYDROSTIM combines the reach of hydraulic fracturing with the simplicity of a matrix treatment — without the special fleet, proppant or reservoir-integrity risk.
A new technology should not be a leap of faith. Before any work begins, we model the HYDROSTIM treatment for the specific well — based on reservoir and well-construction data — and forecast the expected result. You decide on the basis of calculations, not promises.
Send data on your candidate wells. We will provide a preliminary assessment and ranking.
FREE OF CHARGEFor the selected wells — full model, forecast effect and treatment programme, developed and agreed in cooperation with your engineers.
Success criteria (KPIs) are agreed in writing before the job. Standard workover equipment, minimal downtime.
KPIs AGREED UPFRONTA transparent report compares forecast and real results. You scale up only when the numbers confirm it.
Our predictive approach combines modelling of the thermo-baro-chemical process with the results of more than 500 well treatments in 9 countries. The results of every completed treatment are compared with the forecast and used to further refine the model — so each new project rests on an ever wider base of actual field data.
HYDROSTIM’s universality is not a one-size-fits-all compromise. It comes from the controllability of the process: the composition and volumes of the process fluids and the operating regimes of the chemical-technology process (CTP) are designed for the lithology, type of damage and specific conditions of each individual well. That is why the treatment remains targeted and reaches deep into the formation in every application — from tight sandstones to carbonates.
The same engineering discipline applies to well selection. Every candidate is checked against criteria built on more than 25 years of field experience. For a pilot we choose wells within the proven envelope, so that a positive result is as predictable as possible; as the programme scales up across the field, the envelope can be widened step by step.
Components A and B are placed in the sump and across the perforated interval. Gases and active products naturally rise: if the fluids were placed above the perforations, they would escape up the wellbore instead of entering the formation. A well therefore needs a sufficient sump (reaction zone) below or at the pay zone — or the possibility to clean it out to the required depth.
Parameter ranges confirmed by our field experience. The exact values are shared with partners under an NDA.
Wells outside the recommended range can also be considered. After additional analysis and modelling we state the estimated risk openly — and decide together whether to proceed.
A detailed technical questionnaire on well design, reservoir, pressures, production history and fluids — provided after signing an NDA.
Can Components A and B be placed correctly? If not, the well is set aside and we look at the next candidate.
Reservoir and production data are compared with the proven envelope; the remaining potential and the risks are assessed.
The selection criteria and the well questionnaire are shared after signing a mutual NDA — a first step that confirms the commitment of both sides. Or start with a free preliminary screening based on basic well data.
A few basic parameters are enough for a preliminary assessment. Detailed data can follow later. Your data is treated as confidential.
Our technical team will respond within 48 hours.
We will design the optimal stimulation programme purpose-built for your well, your reservoir and your production targets.