HyperSenseIQ is an AI-powered subsurface intelligence platform designed for the Indian oil and gas sector. It takes wireline LAS files and well data as input and delivers instant reservoir characterisation, EOR screening, decline analysis, pressure transient analysis, drilling physics, economics and digital twin outputs — all in a unified browser interface. No installation required.

The core operational engine is entirely deterministic physics — not a neural network, not a black box. Every output is traceable to a named equation and a specific input value. STOIIP uses the standard volumetric equation. Decline uses Arps harmonic. Permeability uses the Craft, Hawkins and Terry Horner method. Every domain score in the EOR ranking is independently visible and challengeable. The AI layer (SWIR spectral engine) is patented and under development — clearly labelled as such.

The minimum requirement is a wireline LAS file with GR, RHOB, NPHI and RT curves, or a structured data sheet with porosity, permeability, pay thickness, water saturation, API gravity and production rate. The platform also accepts pressure buildup CSV files for PTA/RTA analysis. For the built-in demo, no data upload is needed — synthetic data for five Assam and five Mumbai High wells loads automatically.

Data entered in the browser stays in your browser session — it is not transmitted to any server. For PSU clients with strict data sovereignty requirements, a local deployment option is available where the entire platform runs within your own network. No data leaves OIL India or ONGC infrastructure under this arrangement.

Yes. The HyperSenseIQ SWIR spectral intelligence engine is covered by a patent application filed on 24 March 2026 with 11 claims. Six additional claims are drafted. The patent covers the transformer-based mineralogy identification and hydrocarbon contact prediction from hyperspectral core plug images.

The platform applies a five-criterion cutoff system to each depth interval: GR below the shale baseline identifies clean sand; RHOB and NPHI cross-over confirms gas or light oil; RT above the water baseline identifies hydrocarbon bearing zones; Sw calculated from Archie's equation determines fluid type. Zones meeting all criteria are flagged Pay. Zones meeting three or four are flagged Marginal.

Using the standard volumetric equation: STOIIP = 7758 × A × h × φ × (1 − Sw) / Bo, where A is drainage area in acres, h is net pay in feet, φ is effective porosity, Sw is water saturation and Bo is the formation volume factor. Every parameter is visible in the Your Well Data tab and can be adjusted.

It demonstrates the SWIR spectral intelligence engine on synthetic core plug data. Absorption peaks at 1730nm indicate oil signatures, 1900nm indicates brine, and 2200nm and above identify clay minerals, dolomite and mica. The engine cross-checks log-derived water saturation against spectral mineralogy to confirm or challenge the pay zone call. Real core plug image analysis is available for validation engagements.

It computes the full drilling envelope: pore pressure gradient using the Eaton method, fracture gradient using the Hubbert-Willis method, equivalent circulating density accounting for mud rheology and annular pressure losses, and the safe mud weight window. It flags kick risk when pore pressure approaches mud weight and lost circulation risk when ECD approaches the fracture gradient.

Yes, as a pre-drill screening and planning tool. The platform accepts pore pressure, fracture gradient and mud weight as inputs from your drilling records and delivers the safety envelope, ECD and MPD pressure limit. For detailed well design, the outputs inform rather than replace dedicated drilling software.

The platform evaluates eight EOR methods simultaneously: polymer flood, ASP, surfactant, CO2 miscible, steam, SAGD, in-situ combustion and waterflooding. Each method is scored across six scientific domains — Physics, Mechanical, Geological, Chemical, Operational and Techno-Economic. The composite P_EOR score is the weighted average across all six domains. The highest scoring method is the primary recommendation, with the full ranking visible for every well.

Wettability describes whether the rock surface preferentially contacts oil or water. An oil-wet formation is harder to flood efficiently with water. HyperSenseIQ computes a wettability modifier coefficient from API gravity, connate water saturation and irreducible water saturation. This modifier adjusts the EOR score — chemical methods receive a higher uplift in oil-wet reservoirs, waterflood receives a penalty.

A thief zone is a high permeability streak that preferentially accepts injected fluid, bypassing lower permeability pay zones. HyperSenseIQ detects thief zones from the k/phi ratio diagnostic. When detected, it applies a TZ_pen penalty to injection-based EOR methods (waterflood, polymer, ASP) and flags the formation for conformance control evaluation before any injection programme. The diagnostic is now visible directly in the EOR Screening tab.

The Conformance Factor reflects the fitness of formation water chemistry for EOR injection methods. High total dissolved solids (TDS), hardness, scaling ions or incompatible brines reduce the CF_mod score for chemical EOR methods such as polymer and ASP. A CF_mod of 1.0 means the water is clean and unpenalised. Ankleshwar Hazad Member water, for example, carries a CF_mod of 0.68 due to high TDS and sulphate scaling tendency. UST and thermal methods are unaffected by CF_mod. The three modifiers — W_mod, CF_mod and TZ_pen — together adjust the raw EOR score through the master formula: P_EOR_adj = AVG × W_mod × CF_mod × (1 − TZ_pen).

These three modifiers are HyperSenseIQ's reservoir quality adjusters. W_mod (wettability modifier) reflects oil-wet versus water-wet tendencies from API gravity and water saturation data. TZ_pen (thief zone penalty) is triggered when the k/phi ratio exceeds 500 mD/fraction, indicating a high-permeability streak. CF_mod (conformance factor) reflects water chemistry fitness. Together they ensure the EOR ranking is not just based on generic physics but on the specific character of each well's reservoir. All three are now visible as diagnostic cards in the EOR Screening tab.

The Horner method analyses pressure buildup after shutting in a well. It plots shut-in pressure against the logarithm of the Horner time function (tp + Δt)/Δt. The straight line in the middle time region gives slope m, from which permeability k = 162.6qBμ/(|m|h) is calculated. The skin factor S tells you whether the wellbore is damaged (positive skin) or stimulated by fractures or acid (negative skin).

A skin of +5 indicates significant formation damage near the wellbore — likely from drilling mud invasion, scale deposition, clay swelling or fines migration. The well is producing at a fraction of its theoretical rate. A workover or acid stimulation to reduce skin to near zero can substantially restore productivity. The platform recommends intervention when skin exceeds 5.

Yes. Click Upload CSV in the PTA/RTA tab and provide a file with two columns: time_hrs and pressure_psi. The platform parses it automatically, runs the Horner analysis and displays the plot and results within seconds. The built-in synthetic data loads automatically for each well so you can see the capability without any data preparation.

Go to the Chemistry tab and scroll to the bottom. Enter your real formation water ion concentrations — calcium, magnesium, bicarbonate, chloride, sulphate and sodium in mg/L, plus reservoir temperature and field pH. The Saturation Scaling Index (SSI), total dissolved solids, Waterflood Adversity Rating (WFAR) and recommended scale inhibitor dose all compute instantly as you type. Click Reset to dataset defaults to load the pre-calibrated ion profile for whichever formation is selected.

The Stiff-Davis method (1952) is the industry standard for calculating the Saturation Scaling Index in oilfield produced water. It improves on the earlier Langelier index by accounting for ionic strength effects in high-salinity brines — which is essential for Indian formation waters, particularly in Ankleshwar and Cambay where TDS routinely exceeds 30,000 mg/L. A positive SSI means the water is supersaturated with calcium carbonate and will deposit scale. The higher the SSI, the more aggressive the scale treatment required before injection.

WFAR is the Waterflood Adversity Rating — a composite index that reflects how hostile the formation water chemistry is to a waterflood or chemical EOR programme. It is computed from TDS, calcium concentration, sulphate concentration and reservoir temperature, each weighted by their relative impact on polymer and surfactant degradation. A WFAR above 0.6 means waterflood is high-risk without pre-treatment. Values below 0.35 indicate favourable chemistry for injection. The Mumbai High carbonate typically shows WFAR below 0.25 — one reason it is the benchmark field for chemical EOR in India.

The Workflow tab chains all six analytical modules into a single integrated decision for the selected well. Step 1 shows reservoir characterisation from Well Intelligence. Step 2 shows pressure diagnosis from PTA/RTA — permeability and skin. Step 3 shows the EOR intervention decision incorporating skin, wettability and chemistry. Steps 4 to 6 cover chemistry validation, production engineering and decline monitoring. The summary at the bottom gives a plain-language recommendation — whether to acid stimulate, proceed with EOR, or simply monitor. Switch wells and the entire chain updates instantly.

Skin factor from pressure transient analysis is one of the most important inputs to EOR decision-making. A well with skin above 5 should not receive a chemical EOR programme until the damage is removed — the injected chemicals will simply bypass the damaged zone near the wellbore. HyperSenseIQ feeds the PTA-derived skin directly into the EOR score modifier, penalising injection methods for damaged wells and flagging acid stimulation as the correct first intervention. This is the integration that most standalone EOR screening tools miss entirely.

HyperSenseIQ uses a shared integration state that all modules write to and read from in real time. When you run PTA/RTA, the skin and permeability are stored and the EOR module immediately applies a damage penalty to injection methods — visible as a "-skin" tag on the score bars. When you run Nodal Analysis, the operating rate and lift requirement are stored and appear in the Workflow summary. When you use the Live Chemistry Calculator, the SSI and scale risk appear as warnings in the Workflow chain. The platform does not just run modules in isolation — it connects them into one continuous intelligence loop.

Yes, directly and automatically. Skin above 5 applies a 20% penalty to injection EOR methods — polymer, ASP, surfactant and waterflood. Skin between 2 and 5 applies a 10% penalty. The penalised methods show a "-skin" tag next to their score. This is physically correct — injecting into a damaged wellbore wastes chemicals and capital. HyperSenseIQ recommends acid stimulation before EOR for any well with skin above 2, and the Workflow summary states this recommendation explicitly. Run PTA first, then EOR Screening — the platform will connect the two automatically.

The platform uses live Brent crude pricing converted to INR at real-time FX rates. It applies GoI royalty rates, OID cess, GST on services, and ONGC or OIL India equity percentages to compute field-specific NPV and IRR. Payback period and undiscounted cash flow are also shown. All fiscal parameters are editable in the Economics tab for sensitivity analysis.

Arps harmonic decline with b = 0.5 as the default, appropriate for most Indian sandstone reservoirs. The platform computes EUR, remaining reserves, abandonment rate and the Production History Factor (PHF) which validates whether the well's actual decline matches the model. A PHF above 1.1 flags accelerated decline for investigation.

The simplest path is two or three anonymous wells from your field — as LAS files, structured data sheets or direct platform entry. HyperSenseIQ runs the full six-layer analysis and delivers a confidential report. No data leaves your organisation. The outputs are anonymised. This is a zero-risk proof of concept before any formal engagement.

The platform operates on an annual SaaS licence model. Pilot engagements are offered at a fixed project fee. Post-pilot, licensing options include per-well annual, per-field annual and enterprise-wide access. Indian PSU pricing is calibrated for DGH budget cycles. Contact niranjanbilgi@yahoo.com for a formal proposal.

The Mining tab is live with architecture for coalfields (BCCL/CIL Jharia) and iron ore (NMDC Bailadila) as flagship demos. The platform applies analogous intelligence — ore grade distribution, depletion curves, MMDR Act fiscal compliance and recovery optimisation. The mining campaign follows the petroleum pilot validation phase. SWIR spectral analysis applies directly to core drill samples from mineral exploration.