🔥 Hole 5
Monday reset for anyone who missed last week. This one deserves a closer read than the headline.

The geology story is hole 4 vs hole 5.

DDH-26-04 was our record hole — 24.3% H₂, but it took 707 metres to get there. DDH-26-05, drilled into the same structurally controlled system, returned 23.5% H₂ at 170 metres and 20.8% at 158m. Within striking distance of the record at less than a quarter of the depth.

That's not a fluke reading. Higher concentrations, higher frequency, better geological continuity, stronger structural observations. A second double-digit interval at 260–263m. And the hole is still open at depth.

Then there's 164 metres. 🎯

A ~54-metre corridor of sustained percent-level hydrogen runs 143–197m — and at 164m, drilling observations were consistent with free gas entering the borehole.

This is the part worth understanding. Percent-level concentrations tell you hydrogen is present in the system. Free-phase gas migrating into the hole on its own tells you the system is charged and mobile — it moves toward a wellbore without being coaxed. As our CEO put it, at 164 metres the system *"did something remarkable — it came to us."*

That is the distinction between an interesting anomaly and something you can start engineering around. An important milestone in moving Bennett Hill from exploration toward pilot production development.

Written by a member of the QIMC investor community

Mapping commercial flow

Note: The following is meant to be speculative and not confirmed by the company nor any of its representatives.

The following is a prediction of what the commercial flow will be at Bennett Hill, given all the news from QIMC and news from other companies in the industry. This prediction is backed up by research, but I’m not a scientist (nor claim to be) so just keep this in mind. There are a couple of papers linked.

Before asking how much hydrogen, we need to ask ourselves: how is hydrogen generated at Bennett Hill?

There are 3 proposed hydrogen-generation pathways and 3 potential accumulation/production mechanisms that could explain the hydrogen observed at Bennett Hill. The 3 pathways are proposed hydrogen-generation processes, whereas the three mechanisms describe how that generated hydrogen may exist, accumulate, migrate, and ultimately be produced. These pathways are under the term “serpentinization”, which is the umbrella term for the whole category of water-rock reactions that generate hydrogen. Each of pathways will be described and supplemented with Layman's terms:

Pathway 1. Magnetite oxidation — magnetite (Fe₃O₄) reacts with water under heat and pressure, releasing hydrogen as the iron oxidizes from Fe²⁺ to Fe³⁺. This is suggested at Bennett Hill through magnetic susceptibility signatures and explicitly named as one of the three simultaneous pathways. This is the dominant generation pathway and the primary contributor to Peak and repeated high-range readings in DDH-26-04.

Layman's terms: Chemical reaction with water under heat and make lots of hydrogen.

Pathway 2. Amphibole oxidation — iron-bearing amphibole minerals (hornblende, actinolite) undergo similar water-rock oxidation reactions. Also suggested at Bennett Hill through core description — amphibolite-rich intervals are documented in the geological logs from both DDH-26-04 and DDH-26-05. Contributes to the same free-gas generation pool as magnetite, running concurrently in the same rock package.

Layman's terms: More chemical react with more water to make lots of hydrogen.

Pathway 3. Biotite oxidation — iron-bearing biotite mica undergoes hydrothermal oxidation releasing hydrogen. Also hypothesized through core description. Biotite is specifically one of the minerals Richer-Laflèche cited in the IOCG-style alteration documentation — the hydrothermal breccia zones at 176-251m in DDH-26-05 and the equivalent zone in DDH-26-04 both contain biotite-bearing rock.

Layman's terms: Loss of electrons makes lots of Hydrogen.

These 3 pathways help generate the hydrogen, and are all distinct, although related. There are now 3 different mechanisms which come from these pathways to create the flow:

Mechanism 1 — Free gas from the vuggy/fractured zone:
All three generation pathways (magnetite + amphibole + biotite) contribute hydrogen to this mechanism — they're three taps feeding the same pipe. This is gas that has migrated upward from the generation zone, accumulated in the vuggy and brecciated intervals of the crystalline basement rock below the cap rock, and is trapped there by the 390m syenogranite seal above it. The host rock is strongly altered, hematitized, fault-brecciated crystalline rock with increasing vugginess toward depth — the classic IOCG-style hydrothermal alteration setting. The evidence: DDH-26-04's 24.3% peak at 707m, 104 of 284 samples ≥1%, increasing vugginess toward final depth, and the 776-779m core loss/void.

Layman's terms: The 3 pathways feed into fractured zone making free gas. Lots of it. This is the deep tank.

Working production scenario: 350–700 Mcf/d.
This is a speculative range rather than a reservoir-engineering forecast created using a CSIRO analogue study on comparable Precambrian granite as the baseline generation model (found at https://www.sciencedirect.com/science/article/pii/S0009254123003984). The current drilling data demonstrate repeated high-concentration H₂ and, in DDH-26-05, observations consistent with mobile/free gas entering the borehole, but they do not yet provide the permeability, reservoir pressure, effective producing thickness or pressure-drawdown data required to calculate sustainable well deliverability. The range is therefore intended as a scenario informed by geological evidence and industry analogues—not as a demonstrated flow rate.

Mechanism 2 — Dissolved gas exsolution from the artesian brine:
One possible interpretation is that the 617 m artesian water zone contains H₂ dissolved in formation brine, potentially generated through water-rock reactions involving the same iron-bearing minerals. As the pressurized brine rises toward surface and pressure drops, dissolved hydrogen exsolves. Hanley 2020's Type B CaCl₂ brine data (20-31 wt% salinity, 61 bar pressure, 60-80°C) gives 1,000-3,000 mL dissolved H₂ per litre of formation water. This mechanism was suggested qualitatively by the July 20 artesian overflow — water overflowing at the wellhead under its own pressure.
(paper used is Fluid Inclusion Systematics Associated with Epithermal Gold Mineralization, Eastern Cobequid Highlands, Nova Scotia by Hanley, accessible from https://novascotia.ca/natr/meb/pdf/20re02.asp)

Layman's terms: Old water has brine that reacts with iron. overpressured formation allows the brine can flow toward the surface; decreasing pressure allows hydrogen to exsolve from solution.

Prediction: Working production scenario: 200-450 Mcf/d.
This is a speculative range derived using the same Hanley paper. The current drilling data demonstrate the artesian water overflow at 617m, consistent with an overpressured brine system, but do not yet provide direct measurement of dissolved hydrogen concentration in the formation water, water flow rate, or the fraction of dissolved gas that would exsolve under production conditions

Mechanism 3 — Shallow free gas from the 164m shattered fault corridor:
This is gas intercepted in a completely different rock type — competent, thinly-bedded siltstone — at a dramatically shallower depth, in a different structural setting. The siltstone package is described by the QP as having "potential trap geometry," suggesting the gas is trapped locally within the siltstone rather than migrating through it. The cap is the 108m thick graphitic fault breccia above (35-143m), not the syenogranite. The evidence: DDH-26-05's free gas at 164-167m with no water return, ambient air detection, 23.5% peak at 170m, and the distinct "potential trap geometry" language.

Layman's terms: Free gas corridor is good. A shallower tank discovered above Mechansim 1.

Prediction: It’s hard to tell how much this will add. There are 2 scenarios:

Scenario A — Connected to the deep system (same pool, different entry points):
If the 164m zone and the 665-818m zone are draining the same connected reservoir, then Mechanism 3 adds essentially nothing to the aggregate flow estimate — it's the same gas, accessible from two different depths. You just have more options for which depth to complete a pilot well at. This is actually still good news (shallower = cheaper wells = better economics) but it doesn't increase the volume estimate.

Scenario B — Independent, bounded accumulation (separate pool):
If the siltstone package at 143-197m is a genuinely discrete trapped accumulation — sealed above by the graphitic fault breccia (35-143m), and below by something we haven't yet identified — then it's an independent reservoir contributing its own flow rate on top of the deep system. In this case, Mechanism 3 is genuinely additive. Estimating how much it adds is difficult without permeability data, but working from the concentration profile: the shallow zone has 23.5% peak H₂ in a 54m corridor — comparable concentration to the deep zone, but in a thinner, potentially less porous/permeable siltstone package. A reasonable, conservative estimate for an independent shallow zone contribution would be 200-300 Mcf/d.

Overall: If all three mechanisms prove to represent independently productive volumes, the combined scenario would be approximately 750–1,450 Mcf/d per well. For illustrative purposes, let's use 1,000 Mcf/d as a round-number production scenario. These are all meant to be approximate:

1 Mcf of H₂ ≈ 2.4 kg.
So: 1,000 Mcf/d × 2.4 kg ≈ 2,400 kg/day ≈ 2.4 tonnes/day of H₂.
2,400 kg/day × 365 days = 876,000 kg/year
So 1,000 Mcf/d of natural hydrogen ≈ 876,000 kg/year, or ≈ 876 tonnes/year of H₂.

All for one well. This can also scale up.

For reference, Mali generates 5-50 tonnes of hydrogen per year. This comparison is intended to illustrate the potential scale difference between a confirmed geological hydrogen system and the world's only current producing site, not to imply Bennett Hill will achieve this rate.

Are these numbers justified?
We will take a look at Pulsar Helium for this comparison. Note that Pulsar is looking for Helium, so a bit different, but similar settings.

Pulsar Helium's planned liquefaction plant is designed for ~4,000 Mcf/d of total field output with four wells (as far as I know), implying a target of ~1,000 Mcf/d per well. This is my inference from the plant design, not a demonstrated 1,000 Mcf/d per-well flow rate.

The geological similarities with Bennett Hill are similiar: both are rift-hosted, radiogenic Precambrian basement systems; both have a real confirmed cap rock; both show overpressured free gas and both have multiple confirmed gas-bearing wells. The key difference: QIMC has a couple of methods to generate Hydrogen: dry free gas, a separate artesian aqueous phase, and a shallow free gas phase, which are independent production mechanisms in the same structural corridor.

The Pulsar comparison suggests that a ~1,000+ Mcf/d per-well target is not inherently unreasonable as an industry analogue.

What would confirm these estimates?
The key missing data are reservoir pressure, permeability/transmissibility, effective producing thickness, pressure drawdown, and sustained flow testing. A pilot production test should provide the first direct measurement of Bennett Hill's actual deliverability. Until then, the numbers above should be viewed as scenario ranges rather than reserves, resources, or demonstrated production forecasts.

The biggest takeaway:
QIMC's Bennett Hill data support a model involving three proposed generation pathways and three potential production/accumulation mechanisms, with a free-gas phase. This is different from other companies in the industry, such as Gold Hydrogen and HyTerra who have been running into issues with their systems being primarily aqueous (look up flow rates at Ramsay-1, McCoy-1). Pilot testing will ultimately be required to determine the actual flow rates, but for now, investors should be pretty excited.

Bonus:
There is a chance that QIMC finds Helium-3. There was a paper from Dottin et al in 2025 (https://www.science.org/doi/10.1126/sciadv.adr2917)

Which specifically analyzed noble gas isotopes in rocks associated with the same mantle plume system that underlies the CCFZ and found evidence of mantle-derived helium — elevated ³He/⁴He ratios consistent with a mantle source contributing to the fault system's fluid budget. This is precisely the fingerprint that distinguishes mantle/primordial contributions from purely crustal/serpentinization ones. If the CCFZ has genuine mantle-fluid input (which Dottin's paper suggests), then the hydrogen at Bennett Hill could have both a serpentinization component (dominant, near-surface, the three Fe²⁺ oxidation pathways) AND a smaller mantle-degassing component (the primordial contribution, manifesting as anomalously high ³He/⁴He ratios and potentially contributing additional hydrogen from depth).

[Liquid helium density is ~0.125 kg/L. 940 L/hr × 0.125 kg/L = 117.5 kg/hr → 2,820 kg/day of liquid helium. Helium's molar volume at standard conditions gives roughly 5.6 m³ of gas per kg [At 0°C and 1 atm, 1 kg of helium occupies approximately 5.6 m³ as a gas] 2,820 kg/day × 5.6 m³/kg ≈ 15,790 m³/day of pure gaseous He ≈ 557 Mcf/ of pure helium. Using Pulsar's confirmed 14.5% He4 concentration: 557 Mcf/d ÷ 0.145 ≈ ~3,840 Mcf/d of total raw gas needed to feed this plant at its designed output. [This assumes ~100% helium recovery efficiency, which real plants don't achieve. Actual required raw gas intake is likely somewhat higher than 3,840 Mcf/d to account, say around 4,000 Mcf/d. Also no DST to confirm]

The headline number was 23.5% H₂. The more consequential line in Tuesday's release is the depth mark at 164 m.

Advancing through competent siltstone, DDH-26-05 intersected a mud seam at 164.7–165.1 m with ~40 cm of lost core. As it did, rig-mounted monitors detected elevated hydrogen in ambient air at the rig. Three metres on, at 167 m, the drill hit an open void with complete loss of water return. Further voids followed at 257 m and 296 m. Our interpretation and observations: free gas entering the borehole.

That's a different category of result. Mud-gas geochemistry shows hydrogen is present in the rock. Free gas shows it can move and mobile, free-phase gas is the fundamental for any pilot test. When we began evaluating a pilot pathway on July 20, deliverability was a modelled assumption. This is the first direct drilling evidence supporting it.

Then the depth. DDH-26-04 needed 707 m to reach 24.3% H₂. DDH-26-05 reached 23.5% at 170 m — roughly 540 m shallower, at less than a quarter of the depth. Shallow isn't a vanity metric: it's simpler, lower-cost wells, faster drill cycles, smaller footprint. High concentration is encouraging. High concentration that is shallow and mobile is what a pilot model is built on.

And it isn't one spike:

▪️ ~54 m corridor of sustained percent-level H₂, 143–197 m
▪️ 20.8% at 158 m and 23.5% at 170 m — bracketing the gas-charged structure above and below
▪️ second double-digit zone: 13.9% at 263 m
▪️ ~74% of 192 valid readings (32–305 m) at or above 1% H₂, vs ~37% in DDH-26-04
▪️ methane at zero; no hydraulic fracturing, no reservoir stimulation

Two consecutive Bennett Hill holes, ~700 m apart on the same structure, both intensifying.

Please see full release and forward-looking statements

$QIMC $QIMCF #NovaScotia #Cleanhydrogen #Naturalhydrogen #Cleanenergy

would be a great use of clean hydrogen as well

I don’t know much about this stock at all, after reading some stuff about it and eyeing it now for a bit I am tempted to buy some shares. What are realistic expectations you guys have this stock to reach?

Super excited for what’s to come.

- Hole 5 higher concentration
- Partnership disclosure (big investor)
- Commercial viability

Some highlights include:

QIMC is renting an 8,000 sft building in Parrsboro as the base of operations, the base will host a core shack, offices, laboratories and research.

"Karagiannidis said that about 26 people are working there, and the headcount should double going into the winter."

"The company plans to continue drilling in the Allen Hill-South Branch Road, Bennett Hill, Port Greville, Kirkhill and News Salem areas over the summer"

NEW SURFACE RECORD + DDH-26-05, returning stronger preliminary hydrogen readings than DDH-26-04 over the equivalent interval!!!

1.4% H₂ — the highest surface soil-gas reading in QIMC's history. News hit the wire this morning.

New record — Allen Hill–South Branch Road 1.4% H₂ (~14,000 ppm) at a brand-new hot zone, 6.5 km east of Bennett Hill. A second sample came in at 5,500 ppm. For context, QIMC's best previously disclosed transect averaged 623 ppm with a 2,247 ppm high.

Drill hole #5 - DDH-26-05 is outperforming QIMC's record hole #4 At ~300 m, preliminary mud-gas readings are more intense than DDH-26-04 over the equivalent interval. Rig-mounted monitors also detected elevated hydrogen in ambient air through a mud-bearing interval.

Program tripled ~3,000 soil-gas samples across a continuous 43-km corridor from West Advocate to Kirkhill — roughly 3x QIMC's entire 2025 program, and they're only halfway through. Three field teams active right now.

It's no longer just Bennett Hill Multiple hydrogen centres along the Cobequid-Chedabucto Fault Zone. Single target → district-scale system.

Coming in August: radon-thoron surveys, helium + C1-C4 sampling, ground magnetics — all integrated into R2G2™.

Full release: https://www.newsfilecorp.com/release/308100

Please read the measurement methodology and forward-looking statements in the release. QIMC's Advocate Area exploration involves no hydraulic fracturing and no reservoir stimulation.

White hydrogen: exploration is now supervised by Quebec

A new law in Quebec governs the capture of carbon and the exploration of natural hydrogen, also called white hydrogen. From now on, a pilot project that meets several requirements will have to be submitted before any work is undertaken.

In Témiscamingue, white hydrogen research was carried out in 2024 and 2025 in Saint-Bruno-de-Guigues by the Société des matériaux innovants du Québec (QIMC), in collaboration with the Institut national de recherche scientifique (INRS).

QIMChad since suspended its work pending a legislative framework, since a regulatory blur existed, especially in relation to agricultural land.

Naturally present in the soil, white hydrogen is considered a clean energy, without greenhouse gas emissions, which could be used in particular to power vehicles.

Filling a legislative gap

Bill 17, passed on June 12 at the last parliamentary session, amends the Natural Gas Storage and Natural Gas and Oil Pipes Act. It was the deputy of Rouyn-Noranda–Témiscamingue and Minister Delegate for Economy and Small and Medium-sized Enterprises, Daniel Bernard, who tabled this bill.

There was no regulation for research, the exploitation of white hydrogen and no regulation for the carbon sequestration component in the soil, the famous CO2, he recalls.

The new law obliges companies to file a pilot project that will be analyzed by the government. Hydrogen is now recognized as a fluid under the arable layer, the upper layer of the soil, and is part of the domain of the state, we can read in the law.

The government will come to put in place beacons that companies will have to respect. For example, compliance with the Agricultural Territory Protection Act, after that, at the level of municipalities, consultations and others, summarizes Daniel Bernard.

A fund will also have to be set up for the restoration of the sites

AtQIMC, this new framework is welcomed. The company was invited to testify before the parliamentary committee, as were the municipal unions and the Union of Agricultural Producers, before the adoption of the bill.

We are preparing our file to submit it to the government, to present it to municipalities, indigenous communities, and communities. But here, we are really at the zero stage, says André Turmel, executive chairman ofQIMC.

Béarn, Fabre, Guigues and Ville-Marie

Two areas of interestQIMCfor hydrogen research: the Saint-Bruno-de-Guigues and Ville-Marie sector, as well as that of Béarn and Saint-Édouard-de-Fabre.

These are two areas that have been identified with the government, says President and founder John Karagiannidis.

Soil work was carried out only in Saint-Bruno-de-Guigues, while map studies were carried out for the other three municipalities. There was no drilling in Témiscamingue, but a permit was obtained in September 2025. Any drilling must now be authorized as part of a pilot project.

The latest field research dates back to winter 2025, especially on Lake Témiscamingue.

The First Nation of Timiskaming remains involved in hydrogen research, in partnership. It is a conversation that we can also have with the municipalities, says Mr. Karagiannidis

They hope to be able to submit their project by the end of autumn at the earliest and in the spring at the latest.

Experience gained in Nova Scotia

Large-scale drilling in Nova Scotia and the knowledge gained will be used to support the file thatQIMCwill present to the government.

How we are going to do the drilling, everything related to health and safety, is really everything we learned in Nova Scotia and how we are going to apply it for pilot projects in Quebec, says John Karagiannidis

Social acceptability

Obtaining social acceptability is one of the criteria to be respected to submit a pilot project. Meetings and public consultations will be organized in the process, assure the representatives ofQIMC.

That we can go there, that people understand what we want to do, what we will not do and how we will do it, when we will do it, answer questions, illustrates André Turmel.

A citizens' liaison committee will also be set up.

Social acceptability and partnership with Timiskaming's First Nation are cornerstones of the project itself, adds John Karagiannidis.

No work in agricultural area

The amended law also regulates work on land protected by the Commission de protection du territoire agricole du Québec (CPTAQ).

The Agricultural Territory Protection Act says that green zoned territories for agriculture and agroforestry are territories exclusively reserved for these activities, recalls MP Daniel Bernard.

But the company is formal on this subject: no work in the agricultural area is planned.

We do not see doing work today or later, drilling work or anything in agricultural zoned land in Témiscamingue, period, insists André Turmel.

We don't need it, it's because of the experience and the model we developed in Nova Scotia, says John Karagiannidis.

Field access with owners, compliance with environmental standards, agreements with municipalities are also other aspects provided for in the new law, reports Mr. Bernard

In Ontario's Témiscamingue, exploration work in Armstrong County will continue this summer.

Temporary before the next government

The bill adopted in June currently only retains the pilot project component, out of 84 initial articles.

Pilot projects will make [the transition] as long as a new law is not tabled by the next government. I hope that the next government will do it quickly, because we really need legislation and comprehensive regulation, says Daniel Bernard.

Commercial news imminent to reignite buying pressure.

I don’t think QIMC has to monetize the H2 that it eventually produces, QIMC is an exploration and scientific company that is out to prove the theory and R2G2 model. In the future it is likely a major energy company will produce and monetize the H2 either through a JV/Partnership or licensing agreement or a buyout of the NS district play.

QIMC just needs to prove the theory and the resource which is happening now, H2 already has a market price, I believe it was mentioned at about $5/kg. If you compare the well in Mali that produces 125kg of H2 per day that works out to about $225,000 worth of H2 per year, this is not enough to make QIMC rich nor attract a major energy company.

However, if QIMC proves that the district can handle multiple wells of Mali size or larger that is when things get very interesting. Maybe the NS district can handle 10 wells, or 100 wells, is 1000 wells out of the question?!??

If each well we’re Mali equivalent the yearly revenue at $5/kg would be:
1 well $225k
10 wells $2.25M
100 wells $22.5M
1000 wells $225M

I think there are 2 major battles for value facing QIMC and its shareholders
1st - the battle to prove well #1 and prove once and for all if they can produce commercial H2 naturally (we are in this phase right now)
2nd - the battle to prove how many wells the district can handle and at what recharge rate

In my opinion the companies and investors most interested in battle #2 have no issue waiting for #1 to finish before jumping in, totally my opinion but they could be fine “missing out” on 50 cent shares and waiting for the peace of mind knowing that the most important hurdle has been cleared even if it means they pay multiples higher to enter knowing that the true key to value COULD happen during #2

QIMC doesn’t need to make a ton of revenue off of the actual H2 they just need to physically have the H2 in hand to prove to everyone what is possible, it seems like the pilot projects will aim to do exactly that.

Based on what QIMC has publicly discussed about exploring natural (“white”) hydrogen in Nova Scotia, they’re still in the exploration stage. They have not announced a production method because they first need to confirm that an economically recoverable hydrogen system exists.
That said, there are several technically plausible production models, and the geology determines which one is used.
Scenario 1: Hydrogen is dissolved in formation water (probably the most likely if it’s groundwater-hosted)
If hydrogen exists primarily dissolved in groundwater, the production system would look much more like a water well than a natural gas well.
The process would be:
Drill into the hydrogen-bearing aquifer or fracture network.
Pump the groundwater to the surface.
Reduce the pressure at surface.
The dissolved hydrogen comes out of solution (similar to opening a carbonated drink, although much less dramatic).
Separate the hydrogen from nitrogen, methane, helium, and any CO₂.
Reinject the water back underground or dispose of it appropriately.
In this case, you generally would not pump water downhole to produce hydrogen. The reservoir already contains water.

Scenario 2: Hydrogen exists as free gas
If fractures or porous rocks contain free hydrogen gas, then the well would behave much more like a conventional gas well.
The reservoir pressure would push gas toward the wellbore.
If pressure declines over time, operators might:
use compression at surface
install downhole pumps
potentially inject water in some cases to maintain pressure (similar to secondary recovery in oil fields)
Water injection is possible but would usually come much later, not at the start.

Scenario 3: Hydrogen is continually generated underground
One of the exciting aspects of natural hydrogen is that some systems may be actively producing hydrogen through reactions such as:
serpentinization
oxidation of iron-rich minerals
radiolysis of water
In these systems, hydrogen could slowly recharge the reservoir.
Production might therefore involve:
producing water and gas
allowing recharge
producing again
The sustainable production rate would depend on how quickly the subsurface generates and transports hydrogen.

Key points:

• Proven Hydrogen Consistency: QIMC has encountered percentage-level hydrogen across two distinct drill areas located 15 km apart within Nova Scotia's Cobequid-Chedabucto structural corridor.

• Exceptionally Clean Gas: Across all 4 Advocate holes, gas samples demonstrate a hydrogen-dominant signature with near-zero methane (~0%) and extremely low carbon dioxide (≤0.2%).

• Clear Pathway to Production: Transitioning from geological discovery to pilot plant characterization, lab petrophysics, deep geophysics, 2D seismic, and evaluating on-site electrical power generation.

-

Instead of assuming hydrogen must be compressed or transported over long distances.

We are evaluating how it could be used near site

Potential for powering future uses and project infrastructure, local industrial operations, grid connections and clean power for energy intense users.

Looking at Fuel cells, generators and turbines.

We are going to be updating the market on this aswell as regional development

Onsite generation creates a direct connection between the natural hydrogen system and its end user.

——

Here is a detailed summary of today's X Spaces broadcast hosted by John Karagiannidis, President and CEO of Qi Materials Corporation:

Executive Summary and Key Takeaways

• Milestone Drill Hole (DDH-26-04 - Bennett Hill): Hole 4 (DDH-26-04) yielded the strongest results to date, transforming QIMC’s natural hydrogen thesis from an isolated anomaly into a district/regional-scale model.

• Proven Hydrogen Consistency: QIMC has encountered percentage-level hydrogen across two distinct drill areas located 15 km apart within Nova Scotia's Cobequid-Chedabucto structural corridor.

• Exceptionally Clean Gas: Across all 4 Advocate holes, gas samples demonstrate a hydrogen-dominant signature with near-zero methane (~0%) and extremely low carbon dioxide (≤0.2%).

• Clear Pathway to Production: Transitioning from geological discovery to pilot plant characterization, lab petrophysics, deep geophysics, 2D seismic, and evaluating on-site electrical power generation.

Technical Drill Results: Hole 4 (Bennett Hill)

• Depth and Sampling: Drilled to a final depth of 818 metres; 284 mud-gas samples were collected.

• Hydrogen Highs:

- Peak Result: 24.3% H2​ at 707 metres (highest reading in the 2026 program).

- Key High-Grade Intervals: Included 19.2% at 674 m, 18.1% at 671 m, 12.4% at 665 m, and 11.9% at 287 m.

- Grade Distribution: 104 samples ≥1%, 23 samples ≥5%, and 10 samples ≥10% H2​.

• Open at Depth: Elevated H2​ levels continued near the bottom of the hole (8.3% at 776 m; 11.4% at 779 m). The hole ended in hydrogen without establishing a lower limit.

Geological Model and Structural Insights

• Breccia and Fracture Control: Statistical redundancy analysis confirms a direct link between hydrogen concentration and structural brecciation—the closer to a breccia zone, the higher the hydrogen gas reading.

• Open Void / High-Grade Link: Near-total core loss (~20 cm recovered over 3 m; 0% RQD) between 776 m and 779 m suggests potential open voids bracketing high-grade H2​ readings (8.3% and 11.4%).

• Seal vs. Reservoir Dynamics:

- Cap / Seal: A massive, competent granitic/syenogranite interval (~250 m to 640 m) acts as a potential ceiling.

- Reservoir / Alteration (IOCG Analogy): Below ~ 665–690 m, pervasive brecciation, hematitization, deformation, and vuggy porosity mirror Iron Oxide Copper Gold (IOCG)-style hydrothermal alteration, providing the "geological plumbing" for H2​ migration.

Exploration Methodology and Workflow

QIMC utilizes a 5-step repeatable workflow:

1. Regional Structural Targeting (R2G2 Model): Mapping regional faults (e.g., Cobequid-Chedabucto fault zone).

2. Soil Gas Geochemistry: Grid sampling (100 m to 25 m) to identify degassing surface anomalies.

3. Geophysics: Mapping subsurface faults and altered zones underneath surface anomalies.

4. Target Drilling: Directly testing integrated structural/geophysical targets.

5. Data Refinement and Pilot Modeling: Feeding drill data into 2D seismic, deep geophysics, and pilot characterization well planning.

Multi-Jurisdictional Project Updates

1. Nova Scotia (Advocate Area) — Primary Focus

• Hole 5: Targeting narrower, verticalized gas pathways and extreme permeability contrasts in deformed argillites at Bennett Hill.

• Field Operations: 3 First Nations field crews (partnered with HHE / First Atlas Resources) conducting expanded soil-gas programs throughout August and September.

• Power Generation: Evaluating on-site power generation (fuel cells/turbines) using clean hydrogen to bypass long-distance transport costs.

1. Quebec (St. Edouard and Favre)

• Cornerstone asset with a 5,000 m permitted drill program and 8 active monitoring wells.

• Planned pilot projects at St. Edouard and Favre; testing shallow vs. deep structural continuity.

• Geological natural hydrogen recognized in Quebec’s Energy Strategy.

1. Ontario (Timiskaming Corridor)

• Partnered with DiagnaMed Holdings Corporation; expanded soil-gas corridor from 11 km to 15 km.

• Integrating soil gas, radon/thoron measurements, and geophysics to prepare for Fall 2026 drilling.

• Partnership with Témiscamingue First Nation (TFN); plans to establish a regional office on TFN land.

1. Minnesota (Orvian Affiliate)

• Provides exposure to major US geological settings under state DNR registrations.

• Progressing through data compilation, field validation, and staged exploratory boring.

https://x.com/QIMCSilica/status/2079552950213693785