Normal view

Received yesterday — 31 January 2026

Petition of the CERC (Conduct of Business) and (Terms and Conditions of Tariff) Regulations for determination of transmission tariff for HPPTCL – EQ

Summary:

### **1. PETITION OVERVIEW**

* **Petitioner:** Himachal Pradesh Power Transmission Corporation Limited (HPPTCL)
* **Respondents:** Himachal Pradesh State Electricity Board Limited (HPSEBL) and Others
* **Subject:** A petition filed under the **Electricity Act, 2003** and relevant CERC regulations for:
1. **Truing up** of the transmission tariff for the **2019-24** period (adjusting past tariffs based on actual costs).
2. **Determination** of the transmission tariff for the **2024-29** period (setting future tariffs).
* **Assets Involved:** The petition pertains to **three (3) Inter-State Transmission System (ISTS) assets** owned by HPPTCL.

### **2. PROCEEDINGS & COMMISSION’S DIRECTIONS**

During the hearing, the Petitioner’s counsel confirmed the petition’s purpose. The Commission then issued the following procedural and substantive directions:

**A. Procedural Timeline:**
1. **Notice** to be issued to all Respondents.
2. **Respondents** must file their **replies (on affidavit) within two weeks**, with an advance copy to HPPTCL.
3. **HPPTCL** may then file its **rejoinder within one week**.

**B. Specific Information Sought from HPPTCL (on affidavit within two weeks):**
The Commission directed HPPTCL to provide the following critical documents and justifications:
1. **Justification for Weighted Average Rate of Interest (WAROI):** HPPTCL must explain its use of a **10% WAROI** in its calculations.
2. **Tax Documentation:** Submission of **Assessment Orders or Income Tax Returns** for Minimum Alternate Tax (MAT) for Financial Years **2022-23 and 2023-24**.
3. **Detailed Note on Disputed Financial Components:** A comprehensive explanation claiming:
* **Interest on Loan (IoL)** for Asset-1.
* **Return on Equity (RoE)** for all assets in this petition.
* **Critical Context:** The Commission had previously **disallowed** these very components (IoL & RoE) in its past orders dated **16.5.2016 (Petition 119/TT/2014)** and **27.9.2021 (Petition 305/TT/2020)**. HPPTCL must now justify why these claims should be reconsidered.
4. **Auditor’s Certificates:** Submission of auditor-certified statements for the assets covering both the **2019-24 and 2024-29 tariff periods**.

**C. Next Hearing Date:** The petition is scheduled for the next hearing on **19 February 2026**.

### **3. KEY BUSINESS & REGULATORY IMPLICATIONS**

* **Regulatory Scrutiny:** CERC is subjecting HPPTCL’s tariff claims to **rigorous scrutiny**, especially on financial parameters that have been contentious in the past.
* **Critical Financial Disputes:** The core of the inquiry revolves around **Interest on Loan (IoL)** and **Return on Equity (RoE)**, which are major components of the tariff. HPPTCL’s ability to successfully justify these claims, contrary to past rejections, will significantly impact the final approved tariff and its revenue.
* **Data-Driven Justification:** The Commission demands **concrete evidence and detailed justifications** (WAROI rationale, tax proofs, auditor certifications) rather than mere claims, emphasizing **prudence and transparency**.
* **Historical Precedent:** HPPTCL faces an uphill task as it must argue against the **Commission’s own past decisions** that disallowed similar claims. This indicates a potentially significant regulatory hurdle.
* **Impact on Tariff:** The outcome of this petition will determine the **transmission charges** that HPPTCL can levy on users (like HPSEBL) for using its three ISTS assets for the next five years (2024-29) and will settle accounts for the previous five years (2019-24).

For more information please see below link:

Petition for Truing up and determination of the transmission tariff for Combined Asset under “Northern Region System Strengthening Scheme-XV” – EQ

Summary:

### **1. PROCEEDINGS & COMMISSION’S DIRECTIONS**

After hearing PGCIL’s representatives, the Commission issued the following procedural directions:

**A. Timeline for Submissions:**
1. **Respondents** (State Utilities) to file their **replies within two weeks**, with an advance copy to PGCIL.
2. **PGCIL** may file its **rejoinder within two weeks** thereafter.

**B. Specific Information Sought from PGCIL (on Affidavit within two weeks):**
The Commission directed PGCIL to provide detailed, asset-specific information for most petitions. The **common themes** across the data requests are:

1. **Detailed Cost Breakdowns:**
* **Item-wise unit cost** for claimed Additional Capital Expenditure (ACE) related to asset replacement.
* **Element-wise/Party-wise break-up** of capital costs (as on 31.3.2019) and claimed ACE.

2. **Historical Comparison & Justification:**
* **Comparison tables** showing ACE **allowed in previous tariff orders vs. claimed now** for 2019-24, with justifications for any variations.
* **Reconciliation of cost overruns** (e.g., Petition 525/TT/2025 notes a variation of ₹1117.53 lakh).

3. **Regulatory Form Compliance:**
* Submission of specific **Forms (e.g., Form-5, 7B, 9C, 9E, 13)** related to plant & machinery cost, depreciation, and tariff calculations for both 2019-24 and 2024-29 periods.

4. **Technical & Economic Justification for Future Capex (2024-29):**
* **Basis, technical justification, and cost-benefit analysis** for ACE/De-capitalization claimed under **Regulation 25(2) of the 2024 Tariff Regulations**.

5. **Supporting Documentation:**
* **Certificates of obsolescence** from OEMs or competent authorities for replaced equipment.
* **Minutes of relevant committee meetings** approving projects (e.g., NERPC/TCC for Kumarghat substation in Petition 539/TT/2025).
* **Liquidated damages recovery statements** and **initial spares discharge statements**.

### **2. KEY BUSINESS & REGULATORY IMPLICATIONS**

* **Regulatory Scrutiny:** The Commission is conducting a **detailed, granular review** of PGCIL’s capital expenditures, both past (truing up) and future (tariff determination). The focus is on **prudence, justification, and cost-effectiveness**.
* **Focus on ACE:** A significant portion of the inquiry revolves around **Additional Capital Expenditure (ACE)**, indicating scrutiny of project cost overruns, replacements, and upgrades.
* **Transparency & Accountability:** The directives emphasize **transparency** through standardized formats (tables, forms), comparisons with past approvals, and demand for third-party certificates (OEM).
* **Procedure:** The process follows a standard regulatory timeline: **Petition → Hearing → Directions for Information → Respondent’s Reply → Rejoinder → Final Order**.
* **Subject Matter:** The petitions cover a wide range of transmission assets—from system strengthening schemes to project-specific systems—highlighting PGCIL’s ongoing role in national grid development and the subsequent periodic tariff resets.
* **Next Steps:** The matters are **reserved for order** after compliance with the above directions. The final tariff orders will determine the revenue PGCIL can recover from beneficiary states for using these transmission assets for the next five years.

For more information please see below link:

Petition of Hatsun Agro Product Limited for seeking directions upon MSEDCL to allow Net Metering – EQ

Summary:

### **1. BACKGROUND & CONTEXT**

HAPL operates a manufacturing plant in Solapur, Maharashtra, and is an MSEDCL consumer (Consumer No. 341629059470). It had installed a **983 kW rooftop solar system** under a **Net Metering Agreement** with MSEDCL (executed August 2022). HAPL also entered into **Power Purchase Agreements (PPAs)** for captive renewable energy supply through open access.

The dispute arose because after availing **Open Access** for its offsite renewable power, MSEDCL **refused to allow Net Metering** for HAPL’s rooftop solar generation, instead treating it on a **Gross Metering basis** from November 2023 onward. This resulted in significant financial loss to HAPL.

### **2. HAPL’S MAIN PRAYERS**

1. Direct MSEDCL to treat HAPL’s rooftop solar system under **Net Metering** arrangement.
2. Grant **retrospective adjustment** of amounts paid from the start of Open Access (November 2023) based on Net Metering.

### **3. KEY ARGUMENTS OF HAPL**

– HAPL is eligible under **Regulation 3.2** of the Distribution Open Access (DOA) Regulations (Contract Demand > 1 MVA).
– The **DOA (Second Amendment) Regulations 2023** (effective 10 November 2023) **deleted the 8th proviso** that earlier mandated Gross Metering during Open Access.
– New **Regulation 3.4** explicitly permits simultaneous Open Access and Net Metering for eligible consumers.
– MSEDCL’s continued Gross Metering billing is **contrary to the amended regulations**.
– HAPL had repeatedly requested MSEDCL to allow Net Metering (Jan–July 2025) but received no response.
– MSEDCL’s reliance on its own **Clarification Petition (Case No. 232 of 2024)** is misplaced as the regulation is already in force.

### **4. MSEDCL’S DEFENSE**

– At the time of commissioning (Nov 2022), the **DOA (First Amendment) Regulations 2019** applied, which required Gross Metering during Open Access.
– The 2023 Amendment is **prospective**, and HAPL did not apply for **Green Energy Open Access (GEOA)** through the proper **Nodal Agency (MSLDC)** as required.
– MSEDCL filed **Case No. 232 of 2024** seeking clarification on the interpretation of Regulations 3.3 and 3.4, which is still pending.
– Until clarity is provided, existing billing (Gross Metering) continues.
– HAPL’s failure to comply with GEOA procedure renders its claim invalid.

### **5. MERC’S ANALYSIS & RULINGS**

#### **a) Regulatory Framework (Issue a)**
– The **8th proviso of the 2019 Regulations** (requiring Gross Metering during Open Access) was **deleted** in the 2023 Amendment.
– **Regulation 3.4** now explicitly allows **simultaneous Open Access and Net Metering**.
– Since HAPL’s Open Access started in **November 2023**, billing **must follow Net Metering** from 10 November 2023 onward.

#### **b) Compliance with Open Access Procedure (Issue b)**
– MSEDCL delayed implementing the 2023 Amendment until directed by MERC in **Case No. 129 of 2024** (Sept 2024).
– HAPL applied to MSEDCL (as Nodal Agency under earlier rules), and MSEDCL approved monthly Open Access.
– **MSEDCL’s own failure to implement the new system cannot deny HAPL its rightful benefit.**

#### **c) Overlap with MSEDCL’s Clarification Petition (Issue c)**
– In **Case No. 197 of 2024** (July 2025), MSEDCL had already **agreed to provide Net Metering adjustments** subject to the outcome of its clarification petition.
– MERC held that **MSEDCL cannot discriminate** between similarly placed consumers.
– The regulation is **in force**, and MSEDCL must comply.

For more information please see below link:

BHEL issue Tender for Setting Up of 1.3 MW AC Grid Connected Solar PV Plant at Bharat Heavy Electricals Ltd Factory Situated In U.P. – EQ

Summary:

### **1. SCOPE OF WORK (SPD RESPONSIBILITIES)**
– **End-to-End Development**: Design, supply, installation, commissioning, O&M for 25 years.
– **Civil & Structural Works**: Roof strengthening, permanent ladders, drainage, waterproofing.
– **Grid Connectivity**: Evacuation up to BHEL’s substation, including transformers, cables, metering infrastructure.
– **Safety & Monitoring**: CCTV, monkey protection, SCADA, weather monitoring, RFID tagging of modules.
– **Compliance**: All statutory clearances, permits, labor laws, GST, insurance.
– **Water & Auxiliary Power**: Water provided by BHEL at chargeable rates; auxiliary power drawn from grid and netted off.
– **Site Handover**: After 25 years, SPD must either remove plant or hand over in working condition to BHEL at no cost.

### **2. BIDDING PROCESS & ELIGIBILITY**
– **Bid System**: Single-stage, two-envelope (Techno-Commercial & Financial).
– **Eligible Entities**: Indian companies, consortia, foreign companies (must form Indian SPV with ≥51% holding). LLPs not eligible.
– **Pre-Qualification Criteria**:
– **Technical**: Minimum 500 KWp rooftop/land solar plant installed and operational for ≥1 year in last 7 years.
– **Financial**:
– Net Worth ≥ ₹133.64 Lakhs.
– Avg. Annual Turnover ≥ ₹267 Lakhs (last 3 years) OR Line of Credit ≥ ₹167 Lakhs.
– **Experience**: Must provide PO/work completion certificate.
– **EMD**: ₹5 Lakhs (valid 6 months).
– **Performance Bank Guarantee**: ₹33.8 Lakhs (₹20.8L for Jhansi, ₹13L for Varanasi) before PPA signing.

### **3. BID EVALUATION & SELECTION**
– **Techno-Commercial Evaluation**: Compliance with NIT, site visits, document verification.
– **Financial Bid**: Tariff quoted up to two decimals.
– **Reverse Auction**: E-auction for shortlisted bidders (BHEL may decide not to conduct).
– **Selection Criteria**: Lowest tariff (L1) selected; tie-breaker based on earlier bid timestamp.

### **4. KEY CONTRACTUAL & COMMERCIAL TERMS**
– **Tariff**: Fixed for 25 years, inclusive of all taxes (except future Change in Law).
– **Change in Law**: Compensation mechanism via Appropriate Commission; excludes corporate tax changes.
– **Capacity Utilization Factor (CUF)**: Minimum CUF as per Annexure-J (declining from 16.85% in Year 1 to 13.50% in Year 25).
– **Generation Shortfall**: SPD pays compensation = (DISCOM tariff – PPA tariff) × shortfall energy.
– **Excess Generation**: BHEL may purchase excess unless refused; SPD cannot sell to third parties without BHEL’s written consent.
– **Commissioning Timeline**: 6 months from PPA effective date.
– **Delay Penalties**:
– Up to 1 month: 20% PBG encashed.
– 1–3 months: Remaining 80% PBG encashed.
– Beyond 3 months: BHEL may terminate PPA.
– **Financial Closure**: Within 3 months of PPA; delay charges @ ₹1000/MW/day + GST.

### **5. LEGAL & STATUTORY HIGHLIGHTS**
– **GST Compliance**: Mandatory; invoices must match GSTR-2B for credit.
– **Statutory Duties**: PF, ESI, Bonus, Gratuity, Labour Welfare Fund, etc., as per BHEL norms.
– **Dispute Resolution**:
– First: Amicable settlement via BHEL’s Designated Engineer.
– Then: Conciliation as per BHEL Conciliation Scheme 2018.
– Arbitration: Through India International Arbitration Centre (IIAC), New Delhi (for disputes < ₹10 Cr).
– **Jurisdiction**: Exclusive courts in Jhansi/Varanasi.
– **Liability Cap**: Limited to contract price except for fraud, willful misconduct, or IP infringement.

### **6. DOCUMENTATION & FORMATS**
– **Mandatory Formats Provided**:
– Covering Letter, Power of Attorney, Financial Requirement, PBG, Board Resolutions, Consortium Agreement, Technology Declaration, No Deviation Certificate, etc.
– **Submission**: Online via GePNIC portal; digital signature required.

### **7. TECHNICAL SPECIFICATIONS**
– **Modules**: Must be from MNRE’s Approved List of Models & Manufacturers.
– **Warranty**: Modules – 90% output after 10 years, 80% after 25 years; Inverters – 5 years warranty.
– **Standards**: IEC/BIS compliance for modules, inverters, cables, connectors.
– **Monitoring**: SCADA, real-time data to BHEL, RFID tracking for modules.
– **Disposal**: E-waste rules compliance for end-of-life modules.

For more information please see below link:

ACME Solar Secures Long-Term Power Agreement for 250 MW FDRE Project with NHPC – EQ

In Short : ACME Solar has signed a 25-year power purchase agreement with NHPC for a 250 MW firm and dispatchable renewable energy project. The agreement ensures reliable round-the-clock clean power by combining renewable sources with storage solutions, supporting grid stability, enhancing renewable integration, and advancing India’s transition toward a low-carbon and resilient power system.

In Detail : ACME Solar’s signing of a 25-year power purchase agreement with NHPC for a 250 MW firm and dispatchable renewable energy project represents a significant development in India’s clean energy sector. The long-term nature of the agreement highlights growing confidence in hybrid renewable models that can deliver consistent and reliable power.

Firm and dispatchable renewable energy projects are designed to overcome the intermittency challenges associated with solar and wind generation. By integrating multiple renewable sources along with energy storage systems, FDRE projects ensure continuous power supply that closely matches conventional baseload generation profiles.

The partnership between ACME Solar and NHPC reflects an important shift in India’s renewable energy strategy. Rather than focusing solely on installed capacity, the emphasis is increasingly on reliability, availability, and grid integration. This approach supports the evolving needs of utilities and industrial consumers that require dependable power.

Energy storage plays a critical role in the success of FDRE projects. Battery storage systems or other forms of storage allow excess renewable energy to be stored during periods of high generation and released during peak demand. This improves grid stability and reduces dependence on fossil fuel-based peaking plants.

The 25-year duration of the power purchase agreement provides long-term revenue visibility for ACME Solar, enhancing the financial viability of the project. Such long-term contracts help attract investment, reduce financing costs, and support large-scale deployment of advanced renewable technologies.

For NHPC, the agreement strengthens its clean energy portfolio and aligns with its broader diversification strategy beyond hydropower. By procuring firm renewable power, NHPC can offer more reliable green electricity to its customers while supporting national renewable energy targets.

From a system perspective, FDRE projects contribute to better grid planning and operations. Dispatchable renewable power can support load balancing, reduce transmission congestion, and enhance the integration of variable renewable energy across regional and national grids.

The project also reflects India’s evolving regulatory and market framework for renewable energy. Policy support for hybrid and storage-based projects encourages innovation and accelerates the transition from capacity-driven targets to performance-driven energy solutions.

Overall, ACME Solar’s 250 MW FDRE project under a long-term agreement with NHPC represents a key milestone in India’s clean energy journey. It demonstrates how renewable energy, when combined with storage and smart planning, can deliver reliable, scalable, and sustainable power for the future.

Designing an effective strategic stockpiling system for critical minerals – EQ

In Short : Designing an effective strategic stockpiling system for critical minerals involves securing reliable supplies, managing geopolitical risks, and ensuring long-term industrial resilience. A well-structured framework balances national security, economic stability, and sustainability by integrating policy coordination, diversified sourcing, transparent governance, and dynamic inventory management to protect against supply disruptions and market volatility.

In Detail : 2025 was the year when the risks of highly concentrated critical minerals supply chains materialised at scale

The IEA has long warned of the potential security risks associated with the high concentration of critical mineral supply chains. In 2025, these risks became a reality, marking a major turning point for global economic security. The rare earths export controls announced by China in October 2025 posed major national and economic security risks across the world, with potentially severe impacts for a range of strategic sectors including energy, automotive, defence, aerospace, AI and semiconductors. Earlier export controls introduced in April had already resulted in some automotive factories around the world being forced to cut utilisation rates or even temporarily shut down.

Beyond rare earths, export controls have also been imposed on a range of strategic minerals including gallium, germanium, graphite and tungsten, which play a crucial role in strategic applications such as semiconductors, batteries, aerospace and defence. The Global Critical Minerals Outlook 2025 highlighted that China is the leading refiner for 19 out of the 20 strategic minerals closely tracked by the IEA, with an average market share of around 70%. Moreover, over half of these minerals are already subject to some form of export controls. These developments underscore that concentration risks in mineral supply chains are no longer a theoretical concern but pose tangible and growing threats to countries’ economic and national security. Moreover, IEA analysis underlines that the market share of the largest suppliers of key critical minerals, particularly for refining, has been increasing in recent years.

Stepping up global action on critical minerals security has never been more urgent. A clear priority is to develop diversified sources of supply for key critical minerals. However, inevitably, it takes time to develop new projects in both mining and refining. Strategic stockpiling of critical minerals can serve as an important protective measure to safeguard countries from supply shocks and disruptions while they develop new, diversified sources of supply. Strategic stockpiles provide a way for countries to strengthen economic and national security, while also helping to deter future export controls and limiting their impact.

Strategic stocks are an insurance policy against short-term disruptions

Strategic stocks – held specifically for emergency purposes with the involvement of the government – have demonstrated effectiveness across various sectors. A notable example is the oil market, where stockpiles have played an important role in mitigating severe economic impacts for decades. After the oil shock of 1973, IEA member governments established a mechanism to build up and pool emergency oil stocks to protect them from being held to ransom via oil supplies in the future. Since then, the IEA has coordinated five collective responses to major oil supply disruptions, helping to limit the economic impacts of shocks caused by natural disasters or geopolitical strife, most recently in 2022 following Russia’s invasion of Ukraine.

Critical mineral markets operate in a very different context from oil markets. The diversity of critical minerals, each with distinct market contexts, means that stockpiling is not a catch-all solution and its suitability can vary by mineral. It is also not a substitute for efforts to develop diversified supply sources that deliver fundamental security benefits. However, stockpiles can still play an important role in providing emergency supply and protecting industries and jobs. Strategic mineral stockpiles also bring several additional benefits. Even when they are not used, they send a signal to markets that sudden supply shocks or export restrictions need not immediately cripple the system. Some IEA Member countries such as Japan, Korea, and the United States hold strategic stockpiles of critical minerals that have protected industries from supply disruptions.

The build-up of critical minerals stockpiles and the need for stock rotation can also support diversification efforts by sourcing materials from projects outside the dominant suppliers, while also enhancing market transparency by providing governments with insights into pricing.

Strategic stockpiles should primarily serve to ensure business continuity and provide a buffer during supply disruptions, rather than to manage price volatility or influence market dynamics. Clear and transparent principles for stockpile releases, focused on addressing acute and short-term supply interruptions, can help prevent market distortion and maintain healthy investment signals that drive market development.

Designing effective stockpiling systems involves addressing a range of strategic questions including material form, governance model, costs, and financing

Amid mounting risks to mineral supply chains, many countries are showing growing interest in establishing stockpiling systems for critical minerals. In doing so, they need to address a range of strategic questions, including the choice of materials to stockpile, governance models, associated costs and financing mechanisms. Critical minerals vary widely in their physical forms, end-use sectors, market sizes, levels of pricing transparency, warehousing needs, and supply chain complexity. Each material therefore needs to be analysed individually, with stockpiling governance models tailored to its specific characteristics.

As part of the Critical Minerals Security Programme, the IEA has examined these issues in detail and developed a comprehensive database and model covering over 30 forms of strategic minerals that are used in the energy sector and have critical applications in AI, advanced technology, aerospace, and defence. This work involved developing an assessment framework to evaluate the supply and strategic risks for each material across multiple dimensions, exploring potential governance models, understanding warehousing requirements posed by the diverse forms that minerals take along their value chains, building cost models to estimate the expenses associated with stockpiling and examining possible financing mechanisms.

The IEA Critical Minerals Stockpiling Assessment Framework evaluates risks and warehousing needs

To determine which materials should be prioritised for stockpiling, the IEA Critical Minerals Stockpiling Assessment Framework was developed to analyse risks and challenges for each material across multiple dimensions: supply risk, the availability of alternative supply routes, strategic importance and the feasibility of stockpiling.

When evaluating supply risks, the level of supply concentration in both mining and refining is a key factor, as relying on few dominant suppliers means that any disruption can immediately flip markets into shortfall. For gallium, graphite, manganese and rare earths, the top refiner, China, accounts for over 90% of global supply. High price volatility further complicates the development of new supply: for example, lithium, vanadium, rare earths and cobalt have exhibited much higher volatility than oil and gas. Many high-risk minerals are already affected by some form of export restrictions, such as rare earths, gallium, and tungsten, straining their supply chain. These restrictions highlight the supply risks but also indicate the procurement challenges of building strategic stocks for these materials.

The availability of alternative supply routes is another important consideration. For some materials, there are limited options for substitute materials, such as chromium for stainless steel, titanium for alloys requiring a high strength-to-weight ratio, and germanium for high-performance fibre optics, heightening the risks from supply disruptions. Additionally, many materials are produced as co- or by-products alongside other minerals, making their supply less responsive to demand or price signals. For example, gallium is mainly recovered as a by-product of zinc and aluminium production, tellurium from copper and lead, and germanium from zinc and coal.

The strategic importance of each material depends on the sectors in which it is used. When materials have applications in strategic sectors such as semiconductors or defence, their security of supply becomes a crucial factor for economic and national security. While strategic importance can be assessed at the global level, each country should also consider domestic vulnerabilities and dependencies to assess potential impacts on its overall security and resilience.

The feasibility of stockpiling varies by material as each mineral takes different forms along its supply chain. The form most suitable for stockpiling is generally the imported form – most exposed to disruption risks – that can be directly used domestically in case of a disruption, without the need for further processing abroad. A broad assessment of the properties of strategic materials that are imported by IEA Member countries highlights a number of warehousing challenges for certain critical minerals such as hygroscopicity (sensitivity to humidity), reactivity, hazardousness and fragility. For example, lithium hydroxide is highly sensitive to humidity and degrades quickly in air, reducing its shelf life to around six months, while lithium carbonate can be stored for much longer. Gallium has a melting point of around 30°C. These warehousing challenges can be overcome, for example through controlling temperature and humidity of warehouses, using advanced packaging to minimise contact with air and moisture, and rotating stocks of materials with short shelf life. However, these additional requirements increase the cost and complexity of stockpiling.

Stockpiling governance models balance roles between government and industry

There is a spectrum of stockpiling governance models, with suitability varying by country and material. Governance models can be grouped into two broad categories based on where the minerals are physically stored: ‘government-held’ or ‘industry-held’, each with two main options. For government-held (centralised) stockpiling models, the government owns and manages the stockpile, either directly or through a public agency acting on its behalf. Industry-held (decentralised) models require companies to store strategic stocks in addition to their existing commercial inventories. For industry-held stockpiles, stocks may be industry-owned, where the government sets a mandate for a volume to be reserved for emergency use, or government-owned, where industry manages the stocks which are owned and purchased by the government. Companies that participate in these models may receive public support. Governments could also consider leveraging the expertise and assets of commodity traders to manage stockpiles more efficiently.

Most existing strategic critical mineral stockpiling systems are government-held and managed through public agencies. Japan’s mineral stockpiles are managed by its public agency; Japan Organization for Metals and Energy Security (JOGMEC), Korea’s stockpiles are handled through the Korea Mine Rehabilitation and Mineral Resources Corporation (KOMIR) and the Public Procurement Service (PPS), and the United States’ National Defence Stockpile is managed by the Defence Logistics Agency (DLA). China also has major stockpiles of critical minerals, but unlike the others, utilises a combination of governance models with material stored and managed by both government and industry.

Operating costs underpin total stockpiling costs, with financing, warehousing, and discounting as the largest components

The costs of stockpiling are comprised of two primary components: the material purchase cost and the operating cost. The material purchase cost is the significantly larger upfront expense; however, this is a capital cost that is converted into an asset (the stockpile), and the capital is recuperated when stocks are released or during stock rotation (when selling the stock back to the market before reaching the end of their shelf life). The net costs of stockpiling are therefore determined by the operating costs. Stockpiling costs are sometimes misconstrued with an overemphasis on the material purchase cost, whereas operating costs form the actual costs borne over time. The operating cost components include financing, warehousing, discount, logistics, material loss and administrative costs. Financing costs refer to the cost of using debt or equity to purchase the material, warehousing refers to the cost of storing the material, and discount costs reflect the loss in market value when selling the stockpiled material to the market after a period of storage.

Our analysis indicates that financing, warehousing, and discount account for the largest share of total stockpiling operating costs, but there are major differences in the share of each component by material. Financing costs are the largest cost component for high-value, lower volume materials such as gallium and germanium, while warehousing costs become more significant for larger volume, lower-value materials such as synthetic graphite and nickel sulphate. Stricter warehousing requirements can triple warehousing costs per tonne compared with standard metals; however, financing costs remain dominant for many materials, even those with the strictest storage requirements such as lithium hydroxide and rare earth permanent magnets. Materials with shorter shelf lives incur more significant discount costs under government-held models due to more frequent stock rotation. Industry-held governance models reduce these discounts as companies use the stocks directly rather than needing to sell them back to the market.

Stockpiling critical minerals entails relatively modest costs compared with the potential economic impacts of supply disruptions

Analysis of stockpiling costs at the aggregate IEA level indicates that the total net cost of stockpiling most critical minerals is relatively modest, particularly for many high-priority strategic materials such as gallium and germanium, which often involve low volumes. According to our analysis, for all IEA countries to stockpile six months of their exposed imports of gallium metal from the top supplier, the total operating costs of stockpiling would be around USD 800 000. By comparison, costs of stockpiling the same months of exposed imports of rare earth permanent magnets would be almost USD 90 million. For material used in much larger volumes such as lithium hydroxide, the costs only grow to just under USD 300 million.

Government-owned governance models have lower financing costs while industry-led models have lower discount costs and greater efficiencies

The appropriate stockpiling governance model varies considerably by material and depending on domestic context and supply chain structures. Government-owned operating models with access to lower interest rates are most cost efficient for high-value materials, such as gallium or germanium. Lower-volume materials with fewer specifications such as upstream concentrates or midstream rare earth oxides may be more suitable for centralised government-led models, if there are domestic facilities able to process them. However, materials with a wide variety of company-specific specifications, such as graphite anode material or rare earth permanent magnets, or with short shelf lives, such as lithium hydroxide, are often better suited to industry-held governance models, where companies can store the specific materials, they need and undergo stock rotation more efficiently. Government-owned, industry-held governance models combine some of the advantages of both models: reduced financing costs, greater logistical efficiencies and reduced discount costs.

Beyond material characteristics and cost considerations, stockpiling can also support the development of diversified projects. Government-led stockpiling operating models are better suited to procuring material from specific strategic projects, providing offtakes that enhance project viability. In industry-led models, it is harder to control where material is purchased from, but the government could still have a role in aggregating demand. Ultimately, the most suitable stockpiling governance model depends strongly on national circumstances. A hybrid solution using a mixture of governance models for different materials may be optimal for many countries.

There are multiple ways to finance strategic stockpiling, which depend on the governance model and domestic circumstances

In the case of direct management of government-held stocks, purchase and operational costs are typically financed directly from the general budget or through a special purpose fund. In case the government chooses to use a public agency to manage the stocks, it can provide loan guarantee for the initial stock purchase and cover the agency’s operational costs. In an industry-held model, most of the costs are borne by companies, but governments could contribute through several instruments, such as direct loans or loan guarantees, public subsidies, tax breaks or direct equity investments. In the government-owned, industry-held hybrid model, the government would typically cover purchasing and financing costs, while operating costs could be shared through an agreement between government and industry.

The IEA Critical Minerals Security Programme is a key platform for international cooperation on critical minerals stockpiling

The urgency of today’s challenges facing critical mineral supply chains calls for strong international collaboration to achieve greater economic and national security, and stockpiling is a key tool that countries are considering implementing or expanding. While the objective of stockpiles is to strengthen security of domestic supply, coordination with international partners can be beneficial to achieve greater security more efficiently and faster. Coordination on the timing for stockpile purchases and principles for releases could help ensure markets are not distorted. When procuring stocks, countries could also agree to support strategic projects that would increase global diversification or consider aggregating demand. When compatible with domestic policies, countries could also consider to co-locate stocks for greater efficiencies, especially for low-volume materials, or reserve production in countries with production infrastructure to be dedicated to emergency use. Close dialogue among partners also helps transferring knowledge on efficient stockpile management.

The IEA Critical Minerals Security Programme is a key international platform helping countries to explore strategic questions around developing domestic stockpiling systems and opportunities to strengthen international coordination. The Programme will continue to support IEA Members in their efforts on reviewing strategic stockpiling as a tool to enhance preparedness to supply shocks.

Seven recommendations for developing domestic strategic stockpiles of critical minerals

When developing or expanding domestic strategic stockpiles of critical minerals, governments should consider:

  1. Assessing value chains to identify bottlenecks and determine the material portfolio, prioritising those materials with the highest supply risks for a specific country or region.
  2. Stockpiling the form of the material imported to a country or region to enable rapid deployment during disruptions.
  3. Preparing for potential future disruptions by considering materials exposed to major risks that are not yet subject to export restrictions.
  4. Tailoring the stockpiling governance model to the materials of choice, for an overall stockpiling system that optimises cost and benefits.
  5. Setting clear transparent principles for stockpile releases to respond to acute short-term supply disruptions, while maintaining robust investment signals for market development.
  6. Closely involving industry across upstream and downstream sectors to design feasible and effective stockpiling systems and ensure their operational viability.
  7. When compatible with domestic policies, leveraging international collaboration to optimise multiple domestic systems for greater efficiencies.

Petition for Truing up and determination of transmission tariff for the Combined Asset under “Integration of Pooling Stations in Chhattisgarh with Central Part of the Western Region for IPP Generation Projects – EQ

Summary:

—-

### **1. Overview and Context:**
– **Date of Hearing:** 13th January 2026.
– **Common Petitioner:** Power Grid Corporation of India Limited (PGCIL).
– **Subject:** Multiple petitions (listed below) for **truing up of tariffs for the 2019-24 period** and **determination of tariffs for the 2024-29 period** for various transmission assets across India.
– **Regulatory Framework:** Petitions filed under the relevant tariff regulations (e.g., CERC Tariff Regulations, 2019).

### **2. List of Petitions & Key Respondents:**
The petitions involve transmission schemes across different regions. Key respondents are primarily the state power distribution companies (DISCOMs) of the respective beneficiary states.

| Petition No. | Scheme/Project Name | Region | Key Respondent(s) |
| :— | :— | :— | :— |
| **924/TT/2025** | Integration of Pooling Stations in Chhattisgarh… | Western | MPPMCL & 5 Others |
| **926/TT/2025** | System Strengthening XXVI | Southern | TANGEDCO/TNPDCL & 13 Others |
| **921/TT/2025** | System Strengthening Scheme-XIII | Southern | TANGEDCO/TNPDCL & 13 Others |
| **920/TT/2025** | Transmission System for Pavagada Solar Park Phase-I | Southern | TANGEDCO/TNPDCL & 13 Others |
| **962/TT/2025** | Substation works beyond Vemagiri | Southern | TANGEDCO/TNPDCL & 14 Others |
| **964/TT/2025** | WR-NR Corridor for Chhattisgarh IPPs | Northern | UPPCL & 21 Others |
| **413/TT/2025** | North Eastern Region Strengthening Scheme-IV | North Eastern | APDCL & 6 Others |
| **435/TT/2025** | Inter-Regional Strengthening (WR & NR Part-A) | Inter-Regional | MPPMCL & 5 Others |
| **411/TT/2025** | Raipur-Rajnandgaon TL for Chhattisgarh IPPs | Western | MPPMCL & 8 Others |
| **518/TT/2025** | Transmission for Phase-I Gen Projects in Odisha | Western | MPPMCL & 5 Others |
| **420/TT/2025** | Western Region System Strengthening Scheme-V | Western | MPPMCL & 5 Others |
| **731/TT/2025** | *(Details not fully specified in snippet)* | *Not Specified* | *Not Specified* |

### **3. Proceedings and Core Issue:**
– PGCIL, as the Central Transmission Utility (CTU), is seeking **regulatory approval for the final tariffs** for its transmission assets.
– The process involves two key steps for each asset:
1. **Truing Up (2019-24):** Final reconciliation of actual capital expenditure (CAPEX) and operational costs against earlier estimates to determine the final payable tariff for the past period.
2. **Tariff Determination (2024-29):** Setting the approved tariff for the next regulatory period based on the trued-up capital cost and normative operational parameters.

### **4. Business & Regulatory Implications:**

– **For PGCIL:** This is a critical, routine regulatory process to **secure revenue recovery** for its vast transmission investments. Timely and accurate submission of the voluminous data is essential to avoid delays in tariff approval and cash flow.
– **For Respondent DISCOMs:** They have the opportunity to **review and challenge** PGCIL’s cost claims. Their scrutiny is vital to ensure that only prudent and efficient costs are passed through to the end consumers via tariffs.
– **For End Consumers:** The outcome of these petitions will ultimately influence the **transmission component of electricity bills** for consumers in the beneficiary states.
– **For the Power Sector:** The process underscores the **regulated, cost-plus nature of transmission tariffs** in India. It ensures transparency and allows recovery of investments for critical national grid infrastructure.

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For more information please see below link:

TGERC (Licensee’s Duty for Supply of Electricity on Request) Second Amendment Regulations, 2026 – EQ

Summary:

—-

**1. Official Details of the Amendment:**
– **Regulation Name:** Telangana Electricity Regulatory Commission (Licensee’s Duty for Supply of Electricity on Request) Second Amendment Regulation, 2026.
– **Regulation No.:** 01 of 2026.
– **Date of Notification:** 17th January 2026.
– **Effective From:** The date of its publication in the Telangana Gazette.
– **Amends:** The Principal Regulation (No. 4 of 2013) and its First Amendment (No. 1 of 2015).

**2. Primary Objective:**
– To **simplify and expedite** the process for releasing **new LT connections** and **additional loads** in electrified areas.
– To introduce **uniform, objective, and load-based Service Line Charges**, eliminating the need for individual site inspections and case-by-case estimations.

**3. Key Amendments Introduced:**

**A. New Service Line Charges (SLC) for Overhead Line Connections (Clause 7.1):**
– Applies to new/additional **LT connections** (excluding LT-VIII: Temporary supply & Electrification of Layouts) within **1 km of an electrified network**.
– Charges are **per kW of contracted load** and vary by consumer category.
– **Excludes** cost of terminal and metering arrangements (borne by licensee).
– **Distribution Licensee must supply and erect the Distribution Transformer at its own cost and maintain it.**

**B. Category-wise Service Line Charges (Rs./kW):**

| Category | Load Bracket | Service Line Charges |
| :— | :— | :— |
| **LT-I: Domestic** | Up to 1 kW | ₹500 |
| | Above 1–5 kW | ₹500 + ₹600/kW |
| | Above 5–20 kW | ₹2,900 + ₹1,500/kW |
| | Above 20 kW | ₹10,000/kW |
| **LT-II: Non-Domestic/Commercial, LT-VI (Street Lights), LT-VII (General)** | Up to 1 kW | ₹1,000 |
| | Above 1–5 kW | ₹1,000 + ₹1,200/kW |
| | Above 5–20 kW | ₹5,800 + ₹2,000/kW |
| | Above 20 kW | ₹10,000/kW |
| **LT-III: Industries** | Up to 20 kW | ₹4,000/kW |
| | Above 20 kW | ₹10,000/kW |
| **LT-IV: Cottage Industries** | All loads | ₹1,000/kW |
| **LT-V: Agriculture** | All loads | ₹1,000/kW (No ORC from farmers) |
| **LT-IX: EV Charging Stations** | Up to 1 kW | ₹1,000 |
| | Above 1–20 kW | ₹1,000 + ₹1,200/kW |
| | Above 20 kW | ₹8,000/kW |

**Important Note for Apartments/Complexes:** Combined contracted load of the building is considered for levying SLC.

**C. Revised Rules for Development Charges & Transformers (Clause 8.3):**
– **For dedicated transformers** in commercial complexes/apartments **NOT covered under the new SLC system**, the licensee recovers the **full transformer cost**, owns and maintains it, and cannot supply other consumers from it. **No Development Charges** are levied.
– **For connections COVERED under the new SLC system (Clause 7.1):**
– **Load ≤ 20 kW** (individual or combined for buildings): Pay **Development Charges** (as per Schedule) **plus SLC**.
– **Load > 20 kW** (individual or combined for buildings): Pay **SLC only**. **No Development Charges**.

**D. New Clauses Added:**
– **Clause 13:** Empowers the Commission to issue **orders and practice directions** for implementing this regulation.
– **Clause 14:** Grants the Commission the power to **amend, suspend, or repeal** any provision of this regulation in the future.

**4. Business Implications:**
– **For Consumers (Applicants):**
– **Predictable Costs:** Transparent, upfront Service Line Charges based on load and category.
– **Faster Processing:** Simplified process eliminates individual estimations and inspections for standard cases.
– **Lower Cost for Agriculture & Cottage Industries:** Fixed low rate of ₹1,000/kW.
– **EV Charging Support:** Separate, slightly lower tariff slab to promote EV infrastructure.
– **No Transformer Cost:** Licensee bears the cost and maintenance of the distribution transformer for connections under the new SLC system.

– **For Distribution Licensees (DISCOMs):**
– **Streamlined Operations:** Uniform charges reduce administrative burden.
– **Revenue Clarity:** Clear framework for recovering connection costs.
– **Asset Ownership & Maintenance:** Responsible for transformers under the new SLC system.
– **Proposal Right:** Can file for revision of Service Line Charges periodically.

– **For the Regulatory Framework:**
– **Standardization:** Moves away from discretionary site-specific estimates.
– **Promotes Electrification:** Simplified and subsidized rates for key sectors (Agriculture, Cottage Industries, EV).
– **Future Flexibility:** Commission retains power to issue directives and amend rules as needed.

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For more information please see below link:

TGERC (Terms and Conditions of Open Access) First Amendment Regulations, 2026 – EQ

Summary:

—-

**1. Official Details of the Amendment:**
– **Regulation Name:** Telangana Electricity Regulatory Commission (Terms and Conditions of Open Access) First Amendment Regulation, 2026.
– **Regulation No.:** 2 of 2026.
– **Date of Notification:** 24th January 2026.
– **Effective From:** The date of its publication in the Telangana Gazette.

**2. Purpose of the Amendment:**
– To align with clarifications from the **National Load Despatch Centre (NLDC)** regarding issuance of **Renewable Energy Certificates (RECs)**.
– To implement provisions under **Clause 7.2(e)** of the **CERC Procedure for Implementation of REC Mechanism 2024** (dated 07.03.2024).
– To enable **REC issuance to Renewable Energy Generators** for unutilised/banked surplus energy injected into the grid.

**3. Key Amendments to the Principal Regulation (No. 1 of 2024):**
– **Clause 14.11 – Energy Injected Before Wheeling Agreement:**
– Energy injected into the licensee’s network **between the grant of Green Energy Open Access (GEOA) and the submission of a wheeling agreement** will **not be paid for**.
– Such energy will be treated as **inadvertent power**.

– **Clause 33.5 – Issuance of RECs:**
– **Renewable Energy Generating Stations** will now be **entitled to RECs** for the **unutilised banked quantum of energy**.
– Previously, this entitlement was limited to the GEOA consumer; now it extends to the **generator**.

**4. Business Implications:**
– **For Renewable Energy Generators:**
– Can now monetise **surplus/unutilised banked energy** through RECs, improving project economics.
– Provides an additional revenue stream and enhances the viability of green energy projects.

– **For Open Access Consumers:**
– No change in REC entitlement for consumers—they remain eligible as before.
– Clarifies treatment of energy injected before formal wheeling agreements.

– **For Distribution Licensees (DISCOMs):**
– Clear guidelines on handling **inadvertent injection** during the pre-wheeling phase.
– No payment obligation for such energy.

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For more information please see below link:

India Achieves Historic Clean Energy Milestone with 34.6 GW Non-Fossil Capacity Addition in FY26 – EQ

In Short : India added a record 34.6 GW of non-fossil fuel power capacity in the first eight months of FY26, according to the Economic Survey 2026. The achievement highlights rapid progress in renewable energy deployment, strengthening the country’s clean energy transition and reinforcing its commitment to reducing carbon emissions and building a sustainable power system.

In Detail : India has recorded its highest-ever addition of non-fossil fuel power capacity, with 34.6 GW installed in the first eight months of FY26, as highlighted in the Economic Survey 2026. This milestone reflects the accelerating pace of India’s energy transition and demonstrates strong momentum in the deployment of renewable and clean energy technologies across the country.

The non-fossil capacity addition includes major contributions from solar, wind, hydro, and other renewable sources. Solar energy continues to dominate new installations, supported by falling costs, improved technology, and strong policy backing, while wind power and hydro projects are also contributing to diversifying the clean energy mix.

This rapid capacity growth is a direct outcome of India’s long-term national targets for renewable energy and climate action. The government has set ambitious goals to expand non-fossil fuel capacity and reduce dependence on coal, aligning domestic energy policies with global climate commitments and sustainability objectives.

The record capacity addition highlights strong investor confidence in India’s renewable sector. Domestic and international investors are increasingly channeling capital into clean energy projects, attracted by stable policy frameworks, long-term power purchase agreements, and growing corporate demand for green electricity.

From a grid perspective, the large-scale integration of non-fossil capacity is reshaping how India’s power system operates. Grid operators are increasingly focusing on flexibility, storage solutions, and digital systems to manage variability and ensure reliable power supply amid rising renewable penetration.

The growth in clean capacity also supports India’s energy security by reducing reliance on imported fossil fuels. By expanding domestic renewable generation, India can stabilize energy costs, improve trade balance, and enhance resilience against global fuel price volatility.

In addition to environmental benefits, the renewable energy expansion is generating significant economic value. Large-scale projects are creating employment across manufacturing, construction, operations, and maintenance, while also stimulating growth in supporting industries such as energy storage, transmission infrastructure, and digital energy services.

The Economic Survey also reflects a broader structural shift in India’s power sector, where renewables are becoming central to capacity planning and future investments. Clean energy is no longer viewed as a supplementary resource but as the backbone of India’s long-term power strategy.

Overall, the addition of 34.6 GW of non-fossil capacity in FY26 marks a defining moment in India’s clean energy journey. It underscores the country’s ability to scale renewable deployment at record speed and strengthens its position as one of the world’s leading markets for sustainable and low-carbon energy development.

Oswal Greenzo Energies Wins Strategic Green Hydrogen Project at Deendayal Port – EQ

In Short : Oswal Greenzo Energies has secured a 5 MW green hydrogen project at Deendayal Port, marking a significant step in India’s hydrogen journey. The project reflects growing momentum in clean hydrogen adoption and highlights the role of ports as emerging hubs for green energy production, industrial decarbonization, and future-ready sustainable infrastructure.

In Detail : Oswal Greenzo Energies has achieved a major milestone by winning a 5 MW green hydrogen project at Deendayal Port, strengthening its position in India’s emerging hydrogen economy. This project represents a strategic move toward developing large-scale green hydrogen infrastructure and demonstrates the increasing role of private players in supporting national clean energy ambitions.

The project involves setting up a green hydrogen production facility powered by renewable energy sources, ensuring that hydrogen is generated without carbon emissions. This aligns with India’s broader objective of promoting green hydrogen as a key solution for decarbonizing hard-to-abate sectors such as shipping, refining, fertilizers, and heavy industries.

Deendayal Port, one of India’s major ports, is positioning itself as a green energy hub by integrating clean technologies into its operations. By hosting a green hydrogen facility, the port aims to reduce its carbon footprint, improve energy efficiency, and explore alternative fuels for port equipment, logistics operations, and maritime activities.

For Oswal Greenzo Energies, this project strengthens its presence in the green hydrogen segment and expands its clean energy portfolio beyond conventional renewables. The company is expected to leverage its technical expertise to develop efficient hydrogen production systems that can be scaled in the future as demand increases.

The 5 MW capacity of the project, while modest in scale, is significant as a pilot and demonstration model for larger hydrogen initiatives. Such projects help validate technical feasibility, assess cost structures, and build operational experience that is essential for accelerating commercial adoption across different sectors.

Green hydrogen is increasingly being viewed as a cornerstone of India’s energy transition strategy. It offers a pathway to reduce dependence on fossil fuels, enhance energy security, and create new industrial value chains around electrolyzers, storage systems, transport infrastructure, and downstream hydrogen applications.

Ports are emerging as ideal locations for green hydrogen projects due to their access to land, renewable power connectivity, and proximity to industrial consumers. Hydrogen produced at ports can be used for bunkering, export, industrial fuel, or conversion into green ammonia and other derivatives for global markets.

The project is also expected to contribute to the development of India’s hydrogen ecosystem by encouraging investments, fostering innovation, and creating employment opportunities. As more ports and industrial clusters adopt green hydrogen, it can accelerate the creation of a nationwide hydrogen supply network.

Overall, the green hydrogen project at Deendayal Port marks a meaningful step in India’s clean energy journey. It highlights the growing confidence in hydrogen technologies, the role of infrastructure assets like ports in driving sustainability, and the potential of green hydrogen to reshape the future of energy, industry, and transportation.

Petition for Truing up and determination of the transmission tariff for “Transmission System of Vindhyachal-IV & Rihand-III (1000 MW) Generation Project” in the Western Region – EQ

Summary:

**1. Overview of Petitions**
All three petitions filed by **Power Grid Corporation of India Limited (PGCIL)** seek:
– **Truing up** of transmission tariff for the period **2019–24**.
– **Determination** of transmission tariff for the period **2024–29**.

**2. Petition-wise Summary**

| Petition No. | Scheme / Asset Description | Region | Key Respondents |
|————–|—————————-|——–|——————|
| 1021/TT/2025 | Transmission System for **Vindhyachal-IV & Rihand-III (1000 MW) Generation Project** | Western Region | MPPMCL & 20 others |
| 925/TT/2025 | Transmission System for **Ultra Mega Solar Park in Anantapur, AP – Part A (Phase-I)** | Southern Region | TANGEDCO (TNPDCL) & 14 others |
| 731/TT/2025 | **400 kV S/C Singrauli–Vindhyachal TL** with **(2×250 MW) HVDC Back-to-Back at Vindhyachal (NR-WR)** | Inter-regional | UPPCL & 20 others |

**3. Key Proceedings & Directions from CERC**

– **No replies received** from respondents in any of the three petitions.
– **Fresh notices** to be issued to all respondents.
– **Respondents** given **2 weeks** to file replies; **PGCIL** may file rejoinder within **1 week** thereafter.
– **Next hearing date:** 17 February 2026 at 2:30 PM.

**4. Specific Information/Documents Directed by CERC**

**A. For Petition No. 1021/TT/2025:**
1. **Element-wise capital cost breakdown** (Land, Buildings, Transmission Line, Substation, PLCC, IT, etc.) as of 31.03.2019.
2. **Form 9C** in Excel for both tariff periods.
3. **Liability Flow Statement** in Excel.
4. **Asset-wise LD (Liquidated Damages) recovery details**.
5. **Form 7B** for both periods.
6. **Cumulative depreciation details** for IT & PLCC as of 31.03.2019.

**B. For Petition No. 925/TT/2025:**
1. **Justification for variation** in opening capital cost vs. previous order.
2. **Initial Spares discharge statement**.
3. **Form 5 & Form 13**.
4. **Liability Flow Statements** in Excel.
5. **Form 9C** with proper linkages.
6. **Interest rate calculations** for each loan.
7. **Reconciliation of CFA (Central Financial Assistance) grant** – received, deployed, balance.
8. **Documentary proof of CFA grant utilization**.
9. **Evidence of asset decommissioning**.
10. **Justification for ACE (Additional Capital Expenditure) beyond cut-off date**.
11. **Form 7B** for both periods.

**C. For Petition No. 731/TT/2025:**
1. **Basis, technical justification & cost-benefit analysis** for ACE claimed.
2. **Liability Flow Statements for ACE**.
3. **Justification for variation in ACE vs. previous order**.
4. **Details of spillover works** from 2019–24 to 2024–29 with delay justification.
5. **Form 7B** for both periods.
6. **Clarification on IDC (Interest During Construction)** adjustments previously disallowed.

**5. Key Business & Regulatory Implications**
– **Transparency & Scrutiny:** CERC ensuring rigorous validation of capital costs, grants, and expenditures.
– **Stakeholder Engagement:** Despite no replies, fresh notices indicate emphasis on participatory regulation.
– **Renewable Integration:** Petition 925/TT/2025 relates to solar park evacuation – critical for green energy.
– **Inter-regional Assets:** Petition 731/TT/2025 involves HVDC link between NR & WR – strategic for grid stability.
– **Financial Discipline:** Detailed requirements on LD, ACE, IDC, and grants ensure accountable use of capital.

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For more information please see below link:

Petition for Truing up and determination of transmission tariff for “Integration of Pooling Stations with Central Part of the Western Region for IPP Generation Projects in Chhattisgarh” – EQ

v

Sumamry:

**1. Regulatory Authority**
Central Electricity Regulatory Commission (CERC), New Delhi.

**2. Overview of Petitions**
A **combined proceeding** covering **11 separate tariff petitions** filed by **Power Grid Corporation of India Limited (PGCIL)** for truing up of transmission tariffs for the period **2019–24** and determination of tariffs for **2024–29**.

**3. Common Objective Across All Petitions**
– **Truing Up:** Adjust past tariffs (2019–24) based on actual capital expenditure, operational expenses, and other cost variations.
– **Tariff Determination:** Set new transmission tariffs for the next control period (2024–29) for specified transmission assets/schemes.

**5. Commission’s Directions & Information Requirements**
CERC directed PGCIL to submit detailed financial and technical data in prescribed formats for each petition, including:

– **Form 9C:** Capital cost, financing, and tariff calculation sheets with Excel linkages.
– **Form 7B:** Asset-wise tariff computation.
– **Form 5 & 13:** Asset details, capital expenditure, and initial spares.
– **Liability Flow Statements:** Debt and interest details.
– **IDC (Interest During Construction) Discharge Statements.**
– **Auditor Certificates:** For plant & machinery cost, initial spares.
– **Accumulated Depreciation Details:** For PLCC, IT equipment, etc.
– **ACE (Additional Capital Expenditure) Reconciliation:** Item-wise and party-wise comparison with previous orders.

**6. Key Regulatory & Business Implications**
– **Tariff Stability:** The process ensures predictable and cost-reflective transmission pricing for the next 5 years.
– **Cost Recovery:** PGCIL seeks to recover past under/over-recoveries and secure revenue for future operations.
– **Transparency:** Extensive data submission ensures regulatory scrutiny and stakeholder confidence.
– **Multi-Regional Impact:** Tariffs affect multiple state DISCOMs and power utilities across India.
– **Renewable Integration:** Some schemes (e.g., Pavagada Solar Park) support renewable energy evacuation.

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For more information please see below link:

Tesla top, Energy Dome the highest non-lithium firm in new LDES supplier ranking

29 January 2026 at 13:55
Lithium-ion companies have come out as the top-rated suppliers on a new long-duration energy storage (LDES) leaderboard, while CO2 Battery company Energy Dome is the highest non-lithium company.

Korea Zinc and Alta partner to produce rare earth oxides in the US using permanent magnet waste material

30 January 2026 at 16:30

South Korean metals producer Korea Zinc has signed a strategic partnership with US-based Alta Resource Technologies to produce rare earth oxides for applications including EVs.

The two companies plan to establish a joint venture in the US and build production facilities on the site of Korea Zinc’s US subsidiary to separate rare earth elements using Alta’s biochemical technology. The biochemical process platform technology uses custom-designed proteins to selectively separate and purify low-concentration rare earth elements contained within complex mixtures.

Korea Zinc is building a $7.4-billion integrated smelter in Tennessee to meet demand for supply outside of China.

The JV aims to start commercial operations in 2027, starting with an annual processing and production capacity of 100 tons of high-purity rare earth oxides. The JV plans to gradually expand production.

Production will focus on high-purity rare earth oxides such as neodymium oxide, praseodymium oxide, dysprosium oxide and terbium oxide, using permanent magnet waste located in the US as raw material.

The goal is to establish the foundation for a stable supply chain of rare earth oxides to both South Korea and the US.

Since 2022, Korea Zinc subsidiary PedalPoint has been forming a recycling value chain in the US through strategic acquisitions, including e-waste recycling company Igneo, electronics recycling company evTerra, scrap metal trading company Kataman Metals and IT asset management company MDSi. The recycling business is expected to ensure a stable supply of waste to the JV.

“Following our strategy to play a central role in the Korea-US core mineral supply chain by building a smelter in the US, this collaboration will be an important milestone in the rare earths sector, which has recently become increasingly strategically important worldwide,” said Choi Yoon-beom, Chairman of Korea Zinc.

Source: Korea Zinc

DKEM seeks $57.5 million in twin patent suits against Chinese PV rivals

30 January 2026 at 15:15

Wuxi DK Electronic Materials is pursuing two patent infringement cases against domestic competitors, seeking injunctions, equipment destruction, and combined damages of CNY 400 million ($57.5 million).

Wuxi DK Electronic Materials has filed two patent infringement lawsuits with the Jiangsu High People’s Court against Jiangsu Riyu Photovoltaic New Materials and Suzhou Jinyin New Materials Technology , seeking CNY 200 million in damages and related legal costs in each case.

The company said both filings have been formally accepted and registered by the court, although hearing dates have not yet been scheduled.

The lawsuits concern two Chinese invention patents, ZL201180032359.1 and ZL201180032701.8, covering thick-film conductive paste formulations for semiconductor devices, including solar cells. DKEM said the patents are held by its subsidiary Solamet Electronic Materials and relate to lead-tellurium-lithium and oxide-based paste technologies.

DKEM is seeking injunctions to halt the manufacture, sale, and offering for sale of the allegedly infringing pastes. The company is also requesting the destruction of dedicated production equipment and molds, and compensation for economic losses, enforcement costs, and related expenses.

The patents trace back to the intellectual property portfolio of DuPont’s former Solamet photovoltaic paste business, acquired by another entity in 2021 for $190 million. DKEM later consolidated control of the Solamet assets and associated intellectual property.

Suzhou Jinyin is described in Chinese financial reporting as a leading supplier of front-side silver paste for solar cells, ranking third globally by market share. Founded in 2011, it was later acquired by listed electronics firm Suzhou Good-Ark Electronics. Jiangsu Riyu is a fast-growing paste supplier that filed a Hong Kong listing application in 2025, with plans to expand into n-type and back-contact paste products.

This follows earlier high-value patent actions by DKEM. In 2025, its subsidiary filed a suit against Zhejiang Guangda Electronic Technology seeking similar remedies. A Solamet-linked entity also pursued related claims against Changzhou Juhe New Materials in 2021, with domestic and overseas disputes reportedly settled in August 2022.

Separately, DKEM flagged earnings pressure, forecasting a net loss of CNY 200 million to CNY 300 million for 2025, primarily linked to non-operating factors, according to Chinese financial media.

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