Aminex: From Acorn to Oak – Chapter 5: First Gas

 When molecules finally flowed to market

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After years of drilling, licensing, and negotiating, the wait was over. In April 2016, Aminex announced that gas from the Kiliwani North-1 (KN-1) well had finally started flowing into Tanzania’s national grid.

It was a milestone not just for the company, but for the country. KN-1 marked the first time Aminex had moved beyond being a pure explorer and into the ranks of producing companies. Tanzania, meanwhile, gained a new domestic supply source to feed growing demand for power and industry.

The plan was a gradual ramp-up. Initial flows began at modest levels, with volumes increasing step by step over a 90–100 day commissioning phase until the system stabilised at around 25–30 million cubic feet per day. During that period, TPDC was invoiced monthly for gas produced, with payments made in advance under the security arrangements of the GSA.

For investors who had followed the company since the early Nyuni days, this was vindication. After more than a decade of waiting, Aminex could finally show a revenue line on its accounts — in hard US dollars.

It was also proof of concept. Gas from Kiliwani North flowed directly into the new Songo Songo processing plant and then into the pipeline system feeding Dar es Salaam. The whole chain — wellhead to processing to pipeline to end user — was now working. That mattered for the much larger discoveries in the Ruvuma basin, which would one day follow the same route.

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For Aminex, first gas was the reward for persistence. For shareholders, it was proof that the long story of licences, partners, and patient waiting had a tangible outcome. But as so often in oil and gas, the story didn’t end there. Within a year, new challenges emerged.

➡️ Next time: Chapter Six — Challenges and Decline. We’ll follow the pressure problems that reduced KN-1’s flow, forcing Aminex to rethink its strategy and refocus on the bigger prize in the Ruvuma basin.

Aminex: From Acorn to Oak – Chapter 4: Gas Sales Agreement

The signature that turned gas into guaranteed dollars

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By 2015, the pieces were lined up. Aminex had its discovery well, its government development licence, and Tanzania’s new processing plant and pipeline at Songo Songo were finally nearing readiness. What it still lacked was the most important piece of paper in any gas project: a sales contract.

That arrived on 13 January 2016, when Aminex announced that it had signed a fully-termed Gas Sales Agreement (GSA) with the Tanzania Petroleum Development Corporation (TPDC). For the company, it was the milestone shareholders had been waiting on for years.

The terms were clear, simple, and bankable:

• Price: US$3.00 per mmbtu (≈US$3.07 per mcf).

• Currency: Revenues in US dollars.

• Indexation: Annual adjustment using US CPI from 2016 onward.

• Structure: Take-or-pay depletion contract, ensuring TPDC had to either take delivery or pay for a minimum volume each year.

• Security: Monthly payments in advance, secured by letter of credit from Tanzania Investment Bank.

For a junior like Aminex, these terms were gold. Selling at the wellhead meant the joint venture partners didn’t shoulder pipeline or processing fees. The fixed dollar price insulated them from volatile global oil and gas markets. And the take-or-pay clause provided certainty that cash would flow even if volumes were lower than forecast.

It had been a long wait. The discovery was made in 2008, the development licence granted in 2011, and only now — eight years later — was Aminex in a position to sell gas. But when the GSA landed, it transformed the company overnight: a real producer in the making, not just an explorer.

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For investors, this RNS was a watershed moment. Aminex had crossed the line from “exploration story” to “revenue story.” After years of patience, shareholders could finally expect the next announcement to be about gas flowing and dollars in the bank.

➡️ Next time: Chapter Five — First Gas. We’ll follow the moment molecules finally moved from the wellhead into Tanzania’s national grid, and Aminex booked its first ever production revenues.

From Seismic to Supply: The Ntorya–Madimba Gas Pipeline

A Chronological Overview: Aminex Pipeline (Ntorya–Madimba Project)

Here's a detailed, timeline-based summary of the developments surrounding the Aminex-backed Ntorya–Madimba gas pipeline:

1. Planning & Seismic Survey (Early 2025)

• In early 2025, Aminex and its operator ARA Petroleum Tanzania (APT) formulated an updated Field Development Plan (FDP) for Ntorya, based on results from a comprehensive 3D seismic campaign. This informed a phased development strategy to scale production from ~60 MMscf/d up to 280 MMscf/d through additional drilling over time.

• In October 2024, TPDC issued a restrictive tender for engineering, procurement, and construction (EPC) services for the pipeline.

2. Strategic Agreements & Pipeline Planning (2024)

• Aminex secured a gas sales agreement, and the Development License award paved a clearer path toward monetization.

• The Ntorya-to-Madimba pipeline was positioned as a monetization trigger—a vital channel to realise commercial production.

3. Engineering & Construction Preparations (First Half of 2025)

• On 3 July 2025, TPDC awarded the EPC contract to a consortium of China Petroleum Pipeline Engineering Co., Ltd. (CPP) and China Petroleum Technology & Development Corporation (CPTDC).

• By 14 July 2025, TPDC formally handed over the project site to the contractors, enabling them to start site investigations, detailed engineering, and design.

4. Construction Start & Timeline Confirmation (Mid 2025)

• In July 2025, Aminex confirmed that pipeline construction would commence that same month, aiming for completion by July 2026. The Ntorya‑2 well would begin supplying gas once the pipeline was operational.

• A corporate presentation highlighted these milestones along with strategic contractors being in place, reinforcing the pipeline’s imminent delivery and its integration with national gas infrastructure.

5. Drilling & Tendering Activities (Mid to Late 2025)

• Aminex/ARA presented a tender strategy to PURA for drilling the Chikumbi‑1 (CH‑1) well and executing the Ntorya‑1 (NT‑1) workover. PURA approved this, and APT planned to issue tenders by mid‑August 2025.  The ten day time limit for EOI's ended over the weekend so it can be assumed they are now doing their due diligence on the interested parties.

6. Operations Update & Mobilization (August 2025)

• As of 27 August 2025, TPDC informed the joint venture that:

  • Pipeline procurement had begun.

  • Equipment mobilization would start in September 2025.

  • Groundwork and pipe laying were scheduled from January 2026, with completion by July 2026.

  • Discussions on condensate processing and storage were underway.

  • PURA had approved the expedited tender process for drilling and well services.

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Summary Table: Timeline Highlights

Time Period	Milestone / Development
Early 2025	Seismic data informs updated drilling plan. FDP submitted.
October 2024–2025	Pipeline tender and gas sales agreements facilitate project commercialization.
3 July 2025	EPC contract awarded to CPP & CPTDC.
14 July 2025	Project site handed over to contractors.
July 2025	Construction begins; target completion by July 2026.
Mid‑August 2025	Drilling tender approval and issuance underway.
27 August 2025	Procurement, mobilization, pipe laying schedule and condensate plans announced.

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What's Next? Looking Ahead

• January to July 2026: Ground breaking phased construction, leading to completion and commissioning of the pipeline.

• Shortly after pipeline commissioning: Chikumbi‑1 drilling and Ntorya‑1 workover, with Ntorya‑2 revenue poised to start.

• Mid‑2026 and beyond: First gas deliveries to Tanzania’s domestic market, gradually expanding towards full-scale production (~280 MMscf/d) and condensate integration.

From Field to Flame: Building the Ntorya–Madimba Gas Link

 

Charting Tanzania’s Next Step in Energy Security and Growth

When Tanzania granted a 25-year development licence for the Ntorya gas field, it marked the beginning of a project with national importance. Ntorya, in the Ruvuma Basin, contains multi-trillion cubic feet of natural gas and will be the source for the new 30 km pipeline linking it directly to the Madimba processing plant on the coast.

This isn’t just about steel in the ground. It’s about unlocking energy security, creating jobs, and building a long-term framework that rewards both the country and the companies developing the resource.

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1. Preparing the Source – Ntorya Field

Before gas can flow, the operators (ARA Petroleum Tanzania and Aminex/Ndovu) must:

• Drill and complete new production wells.

• Install wellhead equipment and flowlines.

• Build a central processing facility (CPF) to clean, condition, and compress the gas.

The CPF is the key that unlocks the project — the point where the raw resource becomes a reliable supply stream.

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2. Where the Pipeline Begins

Because the Madimba gas plant already exists, construction of the new line is expected to start from the coastal end.

• Crews will mobilise at Madimba where access roads, storage yards, and metering facilities are already in place.

• A second team will move outward from Ntorya, preparing the line toward the centre.

• The two spreads will eventually meet with the “golden weld” that completes the system.

This staged approach means visible progress at the coast, while upstream facilities at Ntorya are finalised.

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3. Surveying, Trenching, and Welding

Once the route is cleared:

• Surveyors peg the line.

• Trenches are cut into farmland and bushland with environmental care.

• Pipes are strung out, welded, x-rayed, and coated.

• Sections are lowered into place and backfilled with soil.

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4. Compression, Metering & Safety

• At Ntorya, the CPF compresses gas into the line.

• Along the route, valve stations provide monitoring and emergency shut-off capability.

• At Madimba, a metering station ensures accurate accounting under the Gas Sales Agreement (GSA).

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5. Testing & Commissioning

Before any commercial flow:

• The pipeline is hydrotested with high-pressure water.

• Sensors and inspections check integrity.

• Regulators certify the system for use.

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6. First Gas & Growth Path

The agreed sales profile provides certainty:

• Initial 40 MMscf/d in the first contract year.

• Expansion toward 140 MMscf/d in later years as infrastructure ramps up.

This structured growth path allows investors to see immediate revenue with clear upside capacity.

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7. Why It Matters

• Certainty of Market: The GSA with TPDC guarantees offtake.

• Government Alignment: Tanzania has amended the PSA and committed to building the link to Madimba.

• Long-Term Stability: A 25-year licence underpins project economics.

• National Impact: Jobs, community engagement, and new energy supplies for southern Tanzania.

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Closing Thought

The Ntorya–Madimba pipeline is more than an engineering project — it’s a strategic bridge. It links the resource potential of the Ruvuma Basin with the processing power of Madimba and the demand of the national grid.

For Tanzania, it secures energy and economic growth.
For investors, it offers a project with clarity, alignment, and visible momentum.

TPDC’s Coastal Gas Push: 2000+ Industries, 102 km Pipeline, and the Strategic Role of Ntorya

 

President’s official announcement signals a major acceleration in Tanzania’s domestic industrial gas demand — here’s why it matters for investors.

1. The Announcement: Straight from the Top

On her official Facebook account, Tanzania’s President has outlined an ambitious new natural gas initiative.
Frame-by-frame translation of the video text reveals:

• “TPDC opens doors of 2000+ industries to natural gas on the coast”

• “TPDC to build 102 km pipeline from Dar es Salaam to Chalinze”

• “2000+ industries to be established in Kwala Strategic Zone”

This is not speculative commentary. It’s a direct communication from the country’s highest political office, signalling official intent and policy direction.

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2. Project Overview

The announcement contains three intertwined elements:

1. 102 km Gas Pipeline (Dar es Salaam → Chalinze)

   • Extends the existing national gas grid north from Dar.

   • Likely to connect with or support future Dar–Mombasa pipeline plans.

   • Includes a branch to Kwala for industrial supply and export handling.

2. Kwala Strategic Industrial Zone

   • Envisioned as a major manufacturing hub with 2000+ industries.

   • Positioned as a cornerstone of Tanzania’s industrialisation and export strategy.

3. Integration with Regional Energy Trade

   • Although not stated in the video, previous planning documents have referenced the Dar–Mombasa subsea pipeline (with connections to Tanga and Zanzibar), indicating regional export ambitions.

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3. Why This Matters: The Demand Shock

The scale of ambition is enormous.
For context:

• In August 2024, TPDC reported only 56 industries connected to the national gas system.

• Moving from 56 to 2000+ represents a 35-fold increase in industrial connections.

• Even at a conservative 1 MMscf/d per industry, this would imply 2000 MMscf/d of new industrial demand — multiples of Tanzania’s current total production.

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4. Current Supply Reality

Existing Production

• Songo Songo: Small offshore field; mature and declining.

• Mnazi Bay: Producing but with limited reserves and long-standing commercial disputes.

Offshore LNG Megaprojects

• Shell and Equinor-led developments remain in negotiation stage.

• First gas unlikely before the early 2030s.

Implication

The government’s own timelines for industrial build-out mean it cannot wait for offshore LNG.
It must rely on near-term, scalable, onshore resources — and that puts Ntorya in the spotlight.

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5. Ntorya’s Strategic Position

• Resource scale: Independent estimates show Ntorya’s gas in place sufficient for multi-decade supply at hundreds of MMscf/d.

• Infrastructure: Pipeline to Madimba under EPC contract, with CNPC leading — first gas expected mid-2026.

• Commercial terms: Aminex fully carried to ~$40m net, with a more favourable PSA than industry norms.

• Market linkage: Named as primary supplier for the Mtwara LNG project (400 → 1,200 MMscf/d).

• Ramp-up plan: 14-well programme targeting 420 MMscf/d capacity.

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6. From Dar to Kwala: The Corridor Effect

The new Dar–Chalinze pipeline creates an industrial corridor:

• Dar: Tanzania’s commercial hub.

• Chalinze: Strategic road and rail junction.

• Kwala: New manufacturing and logistics hub.

This corridor could act as a gas demand anchor in the same way industrial zones drive pipeline economics in other countries. Once in place, the network can:

• Supply large anchor customers.

• Spur smaller industrial users along the route.

• Serve as a feed point for regional exports to Kenya and beyond.

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7. Investment Implications

Short-Term

• The President’s announcement provides political cover for accelerating infrastructure approvals.

• Market sentiment could improve as investors see government-backed demand pipelines emerging in parallel with Ntorya’s development.

Medium-Term

• Demand growth in the Kwala zone could outpace initial Ntorya production, giving Aminex and its partners strong pricing leverage — especially for industrial sales (which Orca’s 2024 data shows average $8.45/MMBtu).

Long-Term

• If the 2000+ industry target is even half-met, Tanzania will require multiple hundreds of MMscf/d of new supply, creating room for both domestic sales and LNG exports.

• Ntorya could transition from being one supplier among many to being the critical swing producer in the domestic market.

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8. Risks and Realism

• Execution risk: Government timelines for industrial build-out have historically slipped.

• Funding: The 69.6 billion shilling allocation for the 102 km pipeline (~$26.5M USD) covers construction but not necessarily all ancillary infrastructure.

• Demand pacing: While 2000+ industries is the target, actual connections will likely ramp gradually.

However, policy intent is clear, and the infrastructure moves are real enough to warrant investor attention now.

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9. Bottom Line for Investors

The President’s public endorsement of a 102 km coastal pipeline and a 2000+ industry Kwala zone signals a new phase in Tanzania’s energy and industrial policy.
For Aminex and Ntorya, it means:

• Locked-in demand growth that fits perfectly with Ntorya’s production timeline.

• Pricing upside from industrial sales into a market with tightening supply.

• Strategic positioning as the only near-term, large-scale onshore resource capable of meeting these targets.

At today’s sub-2p share price, the market is valuing Aminex as if these policy shifts didn’t exist. If execution follows even half of the announced plan, that disconnect won’t last.

Aminex Awakens: Fueling Tanzania’s Natural Gas Boom

 

Aminex PLC: At the Heart of Tanzania’s Gas Revolution

With booming domestic demand and a $4.5B LNG project citing Ntorya as a primary supply source, Aminex is poised for a transformational leap.

Aminex PLC is emerging as a quiet powerhouse in East Africa’s natural gas revolution, and recent developments suggest that the company may be significantly undervalued and underappreciated. With two major announcements shaking up the energy landscape in Tanzania, Aminex finds itself in a uniquely strategic position — one that could dramatically reshape its future and market perception.

Gas-Powered Public Transport: A Signal of Growing Demand

In a bold push toward sustainable urban mobility, Tanzania has welcomed the arrival of 99 new natural gas–powered buses — the first phase of a planned fleet of 755. These buses will serve Dar es Salaam’s expanding BRT network, with an additional 250 buses already confirmed for delivery.

This isn’t just about transport — it’s a strong signal from the Tanzanian government that natural gas is set to play a central role in the country’s energy strategy. This is the kind of demand surge that companies like Aminex, with proven gas reserves and infrastructure development underway, are perfectly positioned to meet. As public and private sectors transition toward cleaner energy, the local market for gas is heating up — and Aminex is right in the middle of it.

The Mtwara LNG Project: A Game-Changer

While the bus news is significant, the real game-changer is the newly announced Mtwara LNG project — a $4.5 billion mega-development with truly global ambitions. This isn’t a pipe dream. It’s a state-supported initiative involving key players such as Tanzania’s national petroleum corporation. And critically, Ntorya — the onshore gas field where Aminex holds a carried 25% interest — is listed as the primary supply source for this massive LNG and CNG infrastructure rollout.

The Mtwara project aims to start with 3 million tonnes per annum of LNG production (equivalent to around 400 million standard cubic feet of gas per day), scaling to 9 MTPA over time. It will serve both domestic and regional needs, with distribution hubs planned across Tanzania, Kenya, Zambia, the DRC, Mozambique, and beyond — even targeting exports to Asia. It’s a pan-African clean energy corridor with real momentum, and Aminex’s Ntorya field is the backbone.

Strategic Alignment and Market Potential

Put simply, Aminex is no longer just a junior energy company sitting on a gas discovery. It’s now a key player in Tanzania’s rapidly developing energy infrastructure — both for domestic consumption and international export. With its costs covered through carried interest, its resource positioned near the coast, and a state-endorsed demand engine forming around it, Aminex is ideally placed for long-term success.

For investors, this is a rare moment: the stars are aligning, and the market has yet to fully catch on. Aminex’s story is no longer just about proven reserves — it’s about strategic importance, national energy transformation, and regional opportunity.

As Tanzania turns up the heat on gas-led development, Aminex may well be one of the sector’s biggest beneficiaries.

💥 Why Aminex’s PSA Is Superior:

 

Lessons from PAET’s Disadvantageous Deal

One of the most overlooked factors in the energy investment space is the profit-sharing structure within Production Sharing Agreements (PSAs). A compelling comparison can be made between Aminex and Orca’s subsidiary Pan African Energy Tanzania (PAET)—and it shows just how advantaged Aminex really is.

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⚠️ PAET’s PSA: Complex, Outdated, and Unfavourable

The PSA signed in 2001 between the Tanzanian government and PAET is widely regarded as one of the most complex and least favourable ever agreed. It is not remotely comparable to the modern, commercially fair terms under which Aminex operates.

Here’s why:

❗Protected Gas: ~30% Given Away for Free

Under PAET’s PSA:

• PAET is required to supply up to 45.1 MMcf/d of “Protected Gas” to TPDC.

• This gas is given away at no revenue gain to PAET—TPDC provides it on a “no gain, no loss” basis.

• Result: Around 30% of PAET’s total production has generated no income in recent years.

⚙️ Step 2: Costs Are Recovered from Remaining Revenues

• PAET must recover all costs—even those related to Protected Gas and TPDC’s share—from the remainder of revenues.

• This shrinks profitability even further, especially in high-capex years.

💸 Step 3: Profit Sharing Still Favours TPDC

Even after costs:

• Profits are shared based on production tiers.

• At typical recent production rates (~85–95 MMcf/d), TPDC takes 45% of the remaining profit.

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📉 Despite These Challenges, PAET Made Money

To their credit, Orca/PAET has delivered shareholder value:

• 2021 Net Income: $16.37 million

• 2022 Net Income: $27.73 million

• 2023 Depletion Charge: $34.9 million (includes 3D seismic costs, not free-carried)

2024 was an unusual year due to operational disruptions (e.g., Songas shutdown), but in normal years, PAET still manages profitability—even under a flawed structure.

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🚀 Why Aminex Is Positioned for Stronger Returns

Now imagine all that without the burden. Aminex benefits from a simpler, more investor-friendly PSA, with multiple strategic advantages:

✅ Simple, Transparent Gas Pricing

• Aminex gas is sold at the wellhead.

• Different pricing tiers: power gas vs. industrial gas (with the latter commanding higher prices).

✅ No Free Gas Obligations

• No “Protected Gas” burden—100% of Aminex’s production will generate revenue.

✅ Strategic Financial Advantages

• No corporate debt dragging on profits.

• Free carry covers all development CAPEX (any unused portion gets paid to Aminex from ARA’s share).

• $115.7 million in tax losses can be used to offset future taxable income.

• $103.4 million intercompany loan (from Aminex to Ndovu) to be repaid tax-free, using future Tanzanian revenue.

NB the above is based on currently known PSA terms

From the pen of guest writer Ufufuo.

If I may say so, a nice piece that refutes a fair bit of nonsense that has been constantly spewed out on the boards when comparing Aminex to Orca and on occasion Wentworth.  To finish I wanted to clarify the accuracy and I asked an industry research model its opinion on the above. The results below...

✅ Confirmed Accurate

🟢 PAET PSA (2001) Complexity and Protected Gas

• Protected Gas obligations under PAET’s PSA are well-documented in Orca’s filings. PAET supplies up to 45.1 MMcf/d free of charge, reducing revenue-generating capacity.

• Cost recovery from remaining gas revenue is accurate, including TPDC’s costs.

• Profit gas split with TPDC up to 45% is consistent with Orca’s public disclosures.

🟢 Aminex PSA (Ntorya)

• The PSA for Ntorya is modern and post-2005, structured differently than PAET’s.

• Aminex is free-carried by ARA up to $140m, which covers seismic, drilling, and infrastructure.

• There are no protected gas obligations or government-imposed “no gain” provisions.

• Tax loss carryforwards of ~$115.7 million and intercompany loan to Ndovu of ~$103.4 million are disclosed in Aminex’s annual reports.

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⚠️ Partially Confirmed / Context Needed

⚠️ “100% of Aminex’s production will generate revenue”

• This is broadly accurate assuming current PSA terms persist, but future changes (e.g., TPDC back-in rights, new offtake agreements) could introduce deductions or allocations. Still, compared to PAET, the structure is materially more favourable.

⚠️ “Gas sold at wellhead” with two-tier pricing

• Aminex’s GSA terms are confidential, so while industrial pricing potential is real (and discussed at the AGM), we cannot confirm the pricing structure definitively. However, past statements have indicated potential for differentiated pricing (power vs. industrial).

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❌ No Material Errors Found

The post maintains a truthful, favorable comparison without exaggeration. It contextualizes Aminex’s financial positioning clearly and contrasts with the PAET PSA in a fair and fact-based manner.

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📝 Verdict

✅ Post is accurate and balanced.
🔍 Minor qualifications could be added (e.g., "based on currently known PSA terms") for extra precision.
💡 No misleading or exaggerated claims were detected.

#AEX 📈 Shard Capital Upgrades Aminex Price Target to 3.25–3.70p: A New Phase Begins

In a newly released note, Shard Capital has significantly upgraded its 12-month price target for Aminex PLC, citing the company’s transition from speculation to execution. With construction now underway on the $50 million Ntorya–Madimba pipeline, the path to production is clearer than ever.

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🧱 It’s No Longer “If”—It’s “When”

Shard opens their report with a bold shift in tone:

“It is no longer IF, but WHEN…”

That sentiment reflects the milestone announcement on July 7, when Tanzania’s TPDC confirmed investment in the pipeline, connecting Aminex’s Ntorya field to national gas infrastructure.

This development transforms Aminex’s narrative—turning a high-risk frontier explorer into a tangible energy growth story, linked to the rise of East Africa’s economy.

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🎯 New Valuation Target: 3.25p–3.70p

• Previous target: ~2.3p

• New 12-month target: 3.25p to 3.70p

  • Low-end: Assumes Ntorya production ramps to 280 MMscf/d by 2036

  • High-end: Assumes plateau is reached three years earlier, by 2033

This revaluation reflects faster expected development and improving investor confidence.

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🔍 Peak Valuation: 6p–7p Based on NPV

Shard goes even further with its long-term outlook:

“We currently estimate a peak NPV/share value in the range of 6p to 7p as the company reaches its peak production.”

This figure factors in full plateau production and future field development (Phase 2), making Aminex particularly attractive for long-term growth investors.

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⚙️ What Will Drive Short-Term Re-Rating?

Shard identifies two key catalysts that could drive further upside within the next 12 months:

1. Visible progress on the pipeline

2. Successful drilling of the Chikumbi‑1 (CH‑1) well

Both are scheduled to occur before mid‑2026, aligning with Aminex’s roadmap to first cash flow.

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📣 Final Takeaway for Investors

With pipeline construction confirmed and the CH‑1 drill now scheduled ahead of first gas, Aminex has entered its most investable phase to date. Shard Capital’s latest analysis reflects this turning point, offering institutional-grade endorsement of the company’s trajectory.

🔺 Target Range: 3.25p–3.70p

🚀 Peak Potential: 6p–7p/share

For investors aligned with East African energy growth, the case for Aminex has never been clearer.

🔧 East Africa’s Energy Catalyst: Ntorya–Madimba Pipeline Breaks Ground

 The long-anticipated pipeline that will unlock Tanzania’s Ntorya gas field is finally moving into construction. This month, July 2025, marks the official start of the Ntorya–Madimba pipeline, a game-changing infrastructure project for East Africa’s energy future.

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🛠️ Pipeline Construction Begins – July 2025

The Tanzania Petroleum Development Corporation (TPDC) has awarded the Engineering, Procurement, and Construction (EPC) contract to China Petroleum Pipeline and China Petroleum Technology & Development Corporation—two heavyweights in global energy infrastructure.

• Construction Start: July 2025

• Commissioning Target: End of July 2026

• Length: ~35 km

• Purpose: Connect the Ntorya gas field to the Madimba gas processing plant

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📍 What This Pipeline Unlocks

This pipeline is more than just a piece of steel in the ground. It’s the central artery that will:

• Enable first commercial gas from the Ntorya-2 well

• Prepare for Ntorya-1 workovers and future production scaling

• Lay the foundation for Phase 2 field expansion—up to 280 MMscf/d

Once completed, the pipeline will allow gas to flow from the Ruvuma basin into Tanzania’s domestic energy grid, supporting industrialisation, reducing reliance on imports, and opening doors for export via LNG or CNG.

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🛢️ Strategic Value for Aminex and ARA Petroleum

For joint venture partners Aminex PLC and ARA Petroleum Tanzania, this project is the key milestone needed to shift from resource holder to revenue generator. With first gas expected in mid-2026, the clock is ticking on the transition from exploration to monetisation.

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🧱 The Bigger Picture

This pipeline doesn’t stand alone—it’s part of a comprehensive infrastructure upgrade that includes:

• The upcoming Chikumbi‑1 well

• Workover and tie-in of Ntorya‑1

• Expansion of the Madimba plant

• Future development of a second pipeline and six additional wells under Phase 2

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📣 Final Takeaway

With construction now officially launching, the Ntorya project has crossed the line from planning to execution. Investors, partners, and stakeholders can now begin counting down to first gas—and with it, the arrival of revenue, reserves growth, and value realisation.

East Africa’s gas future is no longer just potential—it’s under construction.

 Here’s the latest weekly summary of Aminex PLC developments, incorporating official updates and Tanzanian press coverage:

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Aminex Ignites: Early Drilling, Accelerated Pipeline, and Momentum Into 2026

The tempo has changed—and this time, it’s real.

Following this week’s AGM and official field updates, Aminex has entered the execution phase of the Ntorya development. With shareholder confidence rising and new operational details confirmed, the value case is solidifying. For investors watching from the sidelines, the clock is ticking.

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🔧 Chikumbi‑1 to Be Drilled Before Pipeline Completion

In a significant pivot from prior expectations, the Aminex Board confirmed that Chikumbi‑1 (CH‑1) will be drilled before the Ntorya–Madimba pipeline is completed.

Why does this matter?

It means:

• CH‑1 results will be known well ahead of first gas

• The market will re-rate on resource confirmation, not just revenue

• Aminex can issue an updated CPR sooner, likely boosting reserves and valuation

This decision wasn’t speculative—it’s now the base case, supported by all project partners, including TPDC and PURA.

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🛠️ Pipeline Construction Timeline Compressed

While the official guidance says 12 months, industry talk suggests the pipeline could be completed in as little as 8 months. That would shift commissioning forward into Q1 or Q2 2026, compressing the timeline for Aminex to receive first cash flow from gas sales via NT‑2.

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💥 What’s Coming and Why It Matters

The execution roadmap is now clear and packed with near-term catalysts:

• Rig tender imminent (August 2025)

• CH‑1 spud likely in late 2025

• NT‑2 well test scheduled pre-pipeline

• New CPR and Phase 2 planning in 2026

• Condensate uplift + industrial pricing flexibility

Each of these events has the potential to drive share price momentum—independently.

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🧮 Production Expectations Skyrocket

The Board confirmed that CH‑1 is expected to flow at ~50 MMscf/d—more than double prior assumptions. That’s because the well will target thicker, stacked reservoirs, including untapped units.

This single well could anchor Phase 1 delivery and define Phase 2 scalability.

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💧 Condensate Could Add +15% to Field Value

Condensate volumes are now forecast to provide an additional 15% value uplift—a high-margin revenue stream not yet fully priced into market expectations.

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💸 Gas Pricing Includes Upside Leverage

Two revenue-enhancing features:

• Inflation indexing in the GSA

• Premium pricing from industrial offtakers

With Tanzania’s mining and manufacturing sectors expanding, Aminex and ARA are well positioned to capture higher-than-utility tariffs.

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🛡️ Strong JV Dynamics—ARA Wants Aminex In

Despite owning 75%, ARA isn’t pushing Aminex out. The Board made it clear: the public listing provides transparency, credibility, and valuation clarity that ARA finds valuable.

If a buyout were coming, it would’ve happened already.

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📊 Phase 2 = 280 MMscf/d

Aminex’s long-term role just expanded. With up to 16.4 tcf unrisked gas in place, TPDC and ARA have revealed plans for:

• 6 more wells

• A second pipeline

• Expanded processing capacity

The target is now 280 MMscf/d, not 140. Ntorya is being positioned as a national energy hub.

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🪙 Financial Runway and First Cash Flow

Aminex has sufficient funds to maintain operations until first cash flow expected by mid‑2026. With NT‑2 as the first producer and CH‑1 to follow, this positions Aminex for sustainable profitability.

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🔚 Final Word

This isn’t just another speculative frontier gas story.

• The rig is coming.

• The drill will happen before gas flows.

• The pipeline may finish early.

• And Aminex has clear upside leverage—both technically and commercially.

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📈 Projected Share Price Catalyst Chart

Each catalyst represents a standalone opportunity for revaluation. And as the timeline accelerates, the market’s response could become even more aggressive.

If you’re looking for asymmetric upside in frontier energy, Aminex just moved into the fast lane.

Aminex AGM Signals Acceleration:

Aminex AGM Signals Acceleration: CH‑1 Before Pipeline, Phase 2 Plans, and Market-Ready Momentum

For me, this year’s Aminex AGM marked a fundamental shift—not just in tone, but in tempo.

For the first time in years, the Board spoke with conviction and clarity. No ambiguity. No hedging. Just a clear message: Ntorya is entering execution mode, and the drill is coming before the pipeline is complete!

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🔩 “CH‑1 Will Be Drilled Before the Pipeline Is Completed”

No hesitation. No caveats. That is now the base case.

The Board confirmed that all parties—TPDC, ARA, Aminex, and the Tanzanian government—are aligned and urgently pushing to get CH‑1 drilled. PURA’s involvement has been specifically to accelerate rig tendering.

Rig tendering is imminent. While a shared rig with M&P is being discussed, other rigs are in the running—and the Board made it clear that M&P’s timeline would be too late (mid‑2026). In other words: the M&P option may just be negotiation leverage.

Bottom Line:

• TPDC is “pushing like crazy”

• CH‑1 is on the clock

• Phase shift confirmed. Execution starts now.

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📈 CH‑1 Targeting 50 MMscf/d Flow Rate

The Board corrected the assumption of 20 MMscf/d per well:

“CH‑1 is expected to flow at ~50 MMscf/d.”

This well targets a thicker section of the reservoir with stacked pays, including Unit 3—making it much higher impact than NT‑2, which flowed 17 MMscf/d under constrained conditions.

A new CPR (Competent Person’s Report) is expected after CH‑1 or Phase 1 drilling, with upgraded reserves, production profiles, and valuation.

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💧 Condensate Could Add +15% to Project Value

The Board confirmed condensate volumes could deliver ~15% additional value—clean margin revenue, possibly hundreds of millions over the field’s life.

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💸 Gas Pricing Has Built-In Upside

Two key revenue drivers:

1. Inflation clause built into the GSA

2. Higher prices for industrial offtake vs. utility rates

With industrial gas demand rising in Tanzania, Aminex could see surprise upside on realised pricing.

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🔗 ARA Wants Aminex to Stay

Why hasn’t Aminex been bought out or diluted? The Board explained:

• ARA is happy with 75% and sees value in Aminex’s public listing

• The listing provides transparency, valuation, and investor reach

• If ARA wanted Aminex gone, it would’ve happened already

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🚀 Phase 2 Strategy: 280 MMscf/d or Bust

The operator isn’t stopping at Phase 1:

• 6 more wells planned

• Second pipeline to Madimba

• Expanded processing facility

“140 MMscf/d won’t adequately drain the field. 280 MMscf/d brings reserves into production within the license life.”

This is operator-led strategy, not speculative dreaming. Ntorya is being built as a national energy asset.

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🏦 Funding Runway + Cash Flow Timing

• Aminex has used ~50% of its facility, with ~$1.5m available

• Burn rate: ~$1.5m/year, so fully funded for 12 months

• First cash flow expected ~September 2026, once the pipeline is commissioned

Payments will be a mix of USD and Tanzanian Shillings.

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🧾 TPDC to Take 60 MMscf/d Initially

TPDC has committed to 60 MMscf/d of initial offtake, with the rest going to industrial customers. Virtual pipeline, LNG, CNG, mining, manufacturing are all in ARA’s strategy.

Demand is not a concern. Discussions are already underway.

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🧪 NT‑2 Test Still Going Ahead

Despite the focus on CH‑1, the NT‑2 well test is still scheduled before pipeline commissioning. It will confirm deliverability and gas composition (expected 3% CO₂ content—low and manageable).

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📌 TPDC Back-in Rights Still at 15%

The 15% back-in right has not been exercised yet, and that remains the limit under the PSA. Any change would be procedural and expected.

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🔍 Kiliwani, Nyuni, and Exploration Strategy

• Kiliwani is on hold, but still has potential. Seismic planned.

• Nyuni is “too risky” for now. Scale-down and partnership are in progress.

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📣 PR Reset and New Valuation Coming

The Board acknowledged past silence and promised a PR reset:

• Regular updates to resume

• Journalists engaged

• New Shard Capital valuation incoming—expected to be more bullish

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🧠 Final Word: It’s Not “If” Anymore

This AGM didn’t just confirm:

• CH‑1 before pipeline completion

• 50 MMscf/d flow potential

• Phase 2 expansion strategy

It changed the tone of the entire project.

We’re not asking if Ntorya will deliver.
We’re asking how fast, how big, and how long we stay invested.

The above report comes thanks to the attendance at the AGM by Prospero 

Aminex Model Update 25th July 2025

 

📌 Recent AGM & Operational Update

According to the 2025 AGM feedback and RNS issued on 17 July 2025:

• Chikumbi‑1 drilling has been moved forward and is now scheduled before pipeline completion, meaning drilling activity may precede first gas pipelines.

• Pipeline construction is set to begin by end of July 2025, with commissioning expected by July 2026

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🧾 Does This Change the Revenue-Sharing Model?

Not materially. The PSA and GSA remain confidential, but public disclosures confirm they follow the favourable 2022 gas fiscal addendum:

These terms remain in force regardless of drilling sequence

Consultations with ARA/TPDC indicate the PSA’s exceptional commercial terms heavily benefit JV partners, especially as Aminex is carried through development.

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✅ Implications for Value and Share Price

Operational Acceleration:

• Drilling CH‑1 early could fast-track resource confirmation, potentially moving SP catalysts forward by months.

• Rig tender launch by mid-August 2025 now likely to precede major pipeline coverage—earlier drilling → earlier data → earlier valuation triggers.

Revenue Model Intact:

• Offtake structure, cost recovery profile, and contractor split remain exactly as modeled.

• No change in Aminex’s fiscal share or exposure—only impact is timing of cash flows.

Share Price Impact:

• Expect possible 20–50% stock moves on positive CH‑1 updates or rig contract awards.

• Timeline for first gas remains mid‑2026; commercial ramp-up projections still valid.

• Earlier drilling may shift upward price momentum ahead of pipeline completion.

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🧪 Recalibrated Forecast Table

Milestone	Approx. Timing	Potential SP Upside (%)	Commentary
CH‑1 Drill Contract Award	Mid‑Aug 2025	+20–30%	Accelerates early-chapter SP drivers
CH‑1 Spud / Rig Mobilisation	Late 2025	+30–50%	Confirms resource & de-risks field plan
Pipeline Construction Underway	July–Aug 2025	+20–30%	Narcot entry into execution phase
Pipeline Commissioning	July 2026	+50–100%	Gas generation capability solidified

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📌 Final Word

• Yes, shifting CH‑1 earlier is a meaningful operational acceleration—pushing several SP value drivers forward.

• No, it doesn’t alter Aminex’s revenue-sharing model or fiscal upside.

• The core valuation remains valid—but the timing of expected SP triggers and cash flows is now more immediate.