Bihar Gazette, 22 December 2025

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REGISTERED NO. PT.-40

EXTRA ORDINARY

PUBLISHED BY AUTHORITY 1 PAUSHA 1947(S)

(NO.PATNA 1798) PATNA, MONDAY, 22ND DECEMBER 2025 BIHAR ELECTRICITY REGULATORY COMMISSION ——— NOTIFICATION The 26th November 2025 REGULATIONS FOR RESOURCE ADEQUACY FRAMEWORK

No. BERC Case No. 28/2025-07—In exercise of the powers conferred under Section 181 of the Electricity Act, 2003 (36 of 2003), read with section 61, 66, and 86 thereof and all other powers enabling it in this behalf, and after previous publication, the Bihar Electricity Regulatory Commission hereby makes the following Regulations, namely – Bihar Electricity Regulatory Commission (Framework for Resource Adequacy) Regulations, 2025.

Chapter-1 Preliminary

1. Short Title, Extent, and Commencement.—

1.1 These Regulations may be called the Bihar Electricity Regulatory Commission (Framework for Resource Adequacy) Regulations, 2025.

1.2 These Regulations shall extend to the whole state of Bihar 1.3 These Regulations shall come into force from the date of their notification in the Official Gazette.

2. Objective.—

2.1 The objective of these Regulations is to enable the implementation of Resource Adequacy framework by outlining a mechanism for planning of generation resources to reliably meet the projected demand under various scenarios in a cost effective manner. These Regulations further aims to ensure that the load is served reliably in accordance with specified reliability standards, through an optimal capacity mix that promotes efficiency, optimal utilization of resources, sustainability, and grid security.

2.2 The Resource Adequacy frame work shall cover a mechanism for demand2 BIHAR GAZETTE (EXTRA) 22ND DECEMBER 2025 assessment and forecasting, generation resource planning, procurement planning, and monitoring & compliance.

3. Scope and Applicability.—These Regulations shall apply to the generating companies, distribution licensees, State Load Despatch Centre, State Transmission Utility, and other grid connected entities within the State of Bihar.

4. Definitions.—

4.1 In these Regulations, unless the context otherwise requires,

a. "Act" means the Electricity Act, 2003(36 of 2003)and subsequent amendments thereof.

b. "Authority" means Central Electricity Authority referred to in sub-section(1) of Section 70 of the Act.

c. "Capacity Credit" or "CC" means a percentage of a resource's name plate capacity that can be counted towards resource adequacy requirements.

d. "Commission"or "State Commission" means the Bihar Electricity Regulatory Commission (BERC) constituted under the Act.

e. "Expected Energy Not Served" or "EENS" means the expected amount of load (MWh) that may not be served for each year within the time horizon for Resource Adequacy planning.

f. "Long term"means ten years for development of demand forecast, generation resource plan, and procurement plan.

g. "Long Term Distribution Resource Adequacy Plan" or "LT-DRAP" means plan for assessment of long-term resource adequacy by the distribution licensee.

h. "Loss of Load Probability"or "LOLP"means probability that a system's load will Exceed the generation and firm power contracts available to meet that load in a year.

i. "Normalized Energy Not Served" or "NENS" is normalization of the EENS by Dividing it by the total system load.

j. "Planning Reserve Margin" or "PRM" means a specified percentage of available capacity above peak demand as may be stipulated by Authority or Commission for the purpose of generation resource planning.

k. "Resource Adequacy" or "RA" means a mechanism to ensure adequate supply of generation to serve expected demand (including peak, off peak and in all operating conditions) reliably in compliance with specified reliability standards for serving the load in a cost effective manner through an optimum generation mix with a focus on integration of environmentally benign technologies after taking into account the need, inter alia, for flexible resources, storage systems for energy shift, and demand response measures for managing the intermittency and variability of renewable energy sources

l. "Short term" means one year for development of demand forecast, generation resource plan, and procurement plan.

n. "Short-Term Distribution Resource Adequacy Plan" or "ST-DRAP" means plan for assessment of short-term resource adequacy by the distribution licensee.

4.2. All other words and expressions used in these Regulations, although not specifically defined herein above, but defined in the Guidelines for Resource Adequacy Framework issued by Centre Government, Act, or the Guidelines issued there under shall have the meaning assigned to them in the Act. The other words and expressions used herein but not specifically defined in these Regulations or in the Act but defined under any law passed by the Parliament3 BIHAR GAZETTE (EXTRA) 22ND DECEMBER 2025 applicable to the electricity industry in the State shall have the meaning assigned to them in such law.

Chapter- 2

General

5. Resource Adequacy Framework.—

5.1. Resource Adequacy framework entails the planning of generation resources for reliably meeting the projected demand in compliance with specified reliability standards for serving the load with an optimum generation mix.

5.2. Resource Adequacy framework shall cover following important steps:

a) Demand assessment and forecasting b) Generation resource planning c) Procurement planning d) Monitoring and compliance

5.3. The distribution licensee shall develop and prepare Long-Term Distribution Resource Adequacy Plan (LT-DRAP) and Short-Term Distribution Resource Adequacy Plan (ST-DRAP) in accordance with the conditions outlined under these Regulations.

Chapter- 3

Demand Assessment and Forecasting

6. Long-term Demand Forecast.—

6.1. Demand assessment and forecasting is an important step for Resource Adequacy assessment. It shall entail hourly or sub-hourly assessment and forecasting of demand within the distribution area of distribution licensee for multiple horizons (short//long-term) using comprehensive input data, policies & drivers and scientific mathematical modeling tools.

6.2. The distribution licensee shall be responsible for the assessment and forecasting of demand (MW) and energy (MWh) within its own control area.

6.3. The distribution licensee shall determine the load forecast for each consumer category for which the Commission has determined separate retail tariff. 6.4. The distribution licensee shall determine the load forecast for a consumer category by adopting any of the following and/or combination of following methodologies:

(a) compounded average growth rate (CAGR); (b) end use or partial end use. (c) trend analysis. (d) Auto-regressive integrated moving average (ARIMA); (e) AI including machine learning, ANN techniques; (f) econometric (specifying the parameters used, algorithm, and source of

data); and

(g) Any other methodology

6.5. The distribution licensee may use Authority's Electric Power Survey (EPS) projections as base and/or projections arrived applying above-mentioned methodologies after recording the merits of the method. Further, distribution licensee should use best fit of various methodologies for the purpose of demand/load forecast taking into consideration probabilistic modelling approach for various scenarios (viz. most probable, business as usual, aggressive) as outlined under Regulation 6.14 of these Regulations.

6.6. For the purposes of deciding the load forecast for a consumer category and the methodology to be used for load forecasting of a consumer category, the distribution licensee must conduct statistical analysis and shall select the method for which standard deviation is lowest and R-square is highest.

6.7. The distribution licensee shall utilize state-of-the-art tools, scientific and mathematical methodologies, and comprehensive database such as but not limited to weather data, historical data, demographic and econometric data, consumption profiles, impact of policies and drivers etc. as may be applicable to their control area.

6.8. The distribution licensee may modify the load assessed/estimated on either side, for each consumer category, by considering the impact for each of the but not limited to the following activities. The impact shall be considered by developing trajectories for each of the activities based on the economic parameters, policies, historical data, and projections for the future. (a) demand-side management; (b) open access; (c) distributed energy resources; (d) demand response measures; (e) electric vehicles; (f) tariff signals; (g) changes in specific energy consumption, (h) increase in commercial activities with electrification (i) increase in number of agricultural pump sets and its solarization (j) changes in consumption pattern from seasonal consumers (k) availability of supply; AND (l) policy influences such as 24X7 supply to all customers, LED penetration, efficient use of fans/appliances, increased use of appliances for cooking/heating applications, electrification policies, distributive energy resources, storage, and policies, which can impact econometric parameters, impact of national hydrogen mission etc. For each policy, a separate trajectory should be developed for each consumer category.

6.9. The distribution licensee may also take into consideration any other factor not mentioned in Regulation 6.8 of these regulations after recording the merits of its consideration.

6.10. Load profile of the consumer categories for which load research has been conducted may be refined on the basis of load research analysis. A detailed explanation for refinement conducted must be provided.

6.11. The summation of energy forecast (MWh) for various consumer categories upon adjusting for captive, prosumer, and open access load forecast, as obtained as per Regulations 6.4 to 6.10, of these regulations as the case may be, shall be the base data for load forecast for the licensee.

6.12. The licensee shall calculate the load forecasts (in MWh) by adding a loss trajectory approved by the Commission in the latest tariff order. In absence of the loss trajectory as approved by the Commission for the planning horizon, an appropriate loss trajectory stipulated by State or National policies shall be considered with a detailed explanation.

6.13. The peak demand (in MW) shall be determined by considering the average load factor, load diversity factor, seasonal variation factors for the last three years and the load forecasts (in MWh) obtained in Regulation 6.12 of these regulations. If any other appropriate load factor is considered for future years, a detailed explanation shall be provided.

6.14. The distribution licensee shall conduct sensitivity and probability analysis to determine the most probable demand forecast. The distribution licensee must also develop long term demand forecasts for all possible scenarios, while ensuring that at least three different scenarios (most probable, business as usual, and aggressive scenarios) are developed.

7. Short term (Hourly/Sub-hourly) Demand Forecast.—

7.1. The distribution licensee shall develop a methodology for hourly or sub- hourly demand forecasting and shall maintain a historical database.

7.2. For the purpose of ascertaining hourly load profile and for assessment of contribution of various consumer categories to peak demand, load research analysis shall be conducted and influence of demand side management measures, load shift measures, time of use etc. shall be factored in by distribution licensee with inputs from state load dispatch center. A detailed explanation for refinement conducted must be provided.

7.3. The distribution licensee shall utilize state-of-the-art tools, scientific & mathematical methodologies and comprehensive data such as but not limited to weather data, historical data, demographic and econometric data, consumption profiles, policies & drivers etc. as may be applicable to their control area.

8. Aggregation of Forecasted Demand at State.—

8.1. The distribution licensee shall produce hourly or sub-hourly 1-year short-term (ST) forecast and submit it to SLDC by 15th April of each year for the ensuing year.The distribution licensee shall also produce Long term demand forecasts on a rolling basis and submit it to STU by 15th April of each year for the ensuing years.

8.2. STU and SLDC based on the demand estimates of the distribution licensees of the State, shall estimate aggregate demand(MW and MWh) respectively for long-term (rolling basis), and short term for the entire State duly considering the load diversity,congruency, seasonal variation aspects etc.

8.3. The state level demand forecast produced under Regulation 8.2 above shall be submitted by STU (long term) and SLDC (short-term)to the Authority, NLDC and RLDC by 15th May of each year for the ensuring year(s).

Chapter-4 Generation Resource Planning

9. Generation resource assessment and planning is the second step after demand assessment and forecasting and entails assessment of the existing and contracted resources considering their capacity credit and identification of incremental capacity requirement to meet forecasted demand including planning reserve margin.

10. Key contours and important steps in Generation Resource Planning.—

10.1. Generation resource planning shall entail the following steps namely, (a) capacity crediting of generation resources, (b) assessment of planning reserve margin, and (c) ascertaining resource adequacy requirement and allocation for obligated entities.

10.2. The distribution licensee shall map all its contracted existing resources, upcoming resources, and retiring resources to develop the existing resource map in MW for the long term.

10.3. The mapping shall include critical characteristics and parameters of the generating machines, such as heat rate, auxiliary consumption, ramp-up rate, ramp-down rate, etc., for thermal machines; hydrology and machine characteristics, etc., for hydro machines; and renewable resources, their Capacity factors/CUFs, etc. for renewable resource–based power plants to be considered in the resource plan. All the characteristics and parameters with their values for each generating machine considered shall be provided in the resource plan.

10.4. Constraints such as penalties for unmet demand, forced outages, spinning reserve requirements, system emission limits as defined in State and Central electricity grid codes, emission norms specified by the Ministry of Environment and Forest etc shall be identified and enlisted.

10.5. The distribution licensee shall also include a planning reserve as specified by the Authority or Commission, as the case may be. In the absence of any guidelines from the Commission, the distribution licensee can consider suitable planning reserve. The value of planning reserve considered shall be stipulated in the resource plan along with justifications.

11. Capacity Crediting of Generation Resources.—

11.1. Proper estimation of Capacity Credit (CC) is essential for determining the capacity requirements to be tied up by Distribution Licensees for meeting their own as well as coincident peak demand obligations. The Distribution Licensee shall compute the CC factors for its contracted generation resources by adopting the most appropriate methodology from among those recommended in the Guidelines for Resource Adequacy Framework issued by the Ministry of Power, or as specified by the Authority. The Distribution Licensee may adopt any other suitable methodology for computing CC factors, provided that the rationale and merits of such methodology are duly recorded and justified.

11.2. For the purpose of Inter-state contracted RE generation or intra-state RE resources, contribution of CC factor for the RE or generation resource where such resource is located into grid (viz. inter-state or intra-state, as the case may be) as contracted by the distribution licensee shall be considered.

11.3. CC of conventional sources such as coal, gas, nuclear etc can be estimated as: Capacity Credit of Conventional Sources = Installed Capacity *(1 Auxiliary Power) *Availability While computing the Availability of these power plants, the following factors, in addition to other relevant considerations, may also be taken into account:

(i) Fuel availability, planned maintenance, forced outages etc. (ii) For highly seasonal sources such as Hydro(Run of the River; RoR),

Biomass:- Past generation data say for last 5 years

(iii) Hydro generators (with Pondage; dam-based/storage-based) may provide higher output during peak demand hours due to available storage associated with these generators.

11.4. The distribution licensee(s) shall share CC factors for their contracted resources along with justification for its computations with State Load Despatch Center.

11.5 The CC determination exercise shall be undertaken for each year of preceding five years and the average of these CC values for a particular generation resource shall normally be taken as resultant CC value for that resource.

Provided that while computing CC values of preceding years the distribution licensee shall exclude abnormal values attributable to events/circumstances such as act of God, disaster declared by competent authority/Government, act of war etc

11.6. Taking into consideration the methodologies adopted under this Regulation for CC determination, SLDC shall calculate state-specific CC factors considering the aggregate State Demand and contracted RE generation resources available to the State and shall submit such CC factor information to the Authority, NLDC and RLDC from time to time.

12.1. Planning Reserve Margin (PRM) as a percentage of peak load represents the excess generation resource or planning reserve required to be considered for the purpose of generation resource planning.

12.2. Such Planning Reserve Margin (PRM) shall be based on the reliability indices in terms of Loss of Load Probability and Normalized Energy Not Served (NENS), as may be specified by the Authority and the same shall be considered by distribution licensees in their planning for resource adequacy requirement and generation resource capacity planning.

12.3. The capacity planning by the distribution licensee and State level resource adequacy planning by STU/SLDC shall factor in PRM while developing state-level Integrated Resource Plan. 13. Resource Adequacy Requirement and its Allocation.—

13.1. Upon applying CC factors as determined under Regulation 11 of these regulations and determining adjusted capacity for contracted generation resources (existing and planned), the sum of such adjusted contracted generation capacity (existing and planned) over a time axis of 15-minute intervals or longer, but not more than one hour, shall form the resource map of the distribution licensee.

13.2. The distribution licensee shall subtract the resource map developed in regulation 13.1 from the demand forecast developed in regulations 6 and 7 of these Regulations to identify the resource gap. The resource gap in terms of Resource Adequacy (RA) compliance for the distribution licensee for long and short term shall be developed in the manner as specified in these Regulations.

13.3. The distribution licensee shall conduct sensitivity and probability analysis to determine the most probable resource gap. The distribution licensee shall also develop resource gap plans for possible scenarios, while ensuring that at least three different scenarios (most probable, business as usual, and aggressive) are developed.

13.4. Based on most probable scenario, distribution licensee shall undertake development of Long-term Distribution Resource Adequacy Plan (LT- DRAP) and Short-term Distribution Resource Adequacy Plan (ST-DRAP) exercise. The distribution licensee while developing LT-DRAP and ST- DRAP shall be guided by Long-term National Resource Adequacy Plan (LT- NRAP) and Short-term National Resource Adequacy Plan (ST- NRAP).

13.5 The Resource Adequacy Plan will essentially lay down the quantum and type of resources required in the portfolio of a distribution licensee to meet the demand in an optimal (least cost and secure) manner. The plan shall give the year-on-year optimal generation (conventional plus Renewable) and storage capacities required to meet the system demand and the planning reserve margin securely and at least cost.

13.6 Considering State's share in the national peak as allocated in LT-NRAP, SLDC shall allocate each distribution licensee's share in the national peak within 15 days of the publication of LT-NRAP.

13.7 The LT-DRAP and ST-DRAP so developed by distribution licensee shall be submitted to the Authority, STU and SLDC by 15th August of each year.

Procurement Planning

14. Procurement planning shall consist of.—

(a) determining the optimal power procurement resource mix, (b) deciding on the modalities of procurement type and tenure, and (c) engaging in optimum utilisation of contracted capacities and efficient management of surplus energy contracted.

15. Procurement Resource Mix.—

15.1. The distribution licensee in its power procurement strategy shall lay emphasis on the optimal procurement generation resource mix that shall enable smooth RE integration in its portfolio of power procurement resource options while meeting reliability standards.

15.2. For identification of the optimal generation procurement resource mix, optimization techniques and least-cost modelling shall be employed in order to avoid stranding of assets. The distribution licensee shall engage in adoption of least cost modelling and optimization techniques and demonstrate the same in its overall power procurement planning exercise to be submitted to the Commission for approval.

15.3. Procurement by distribution licensees shall be consistent with the identified resource mix and considering overall national electricity plan and policies notified by the Appropriate Government from time to time.

16. Procurement Type and Tenure.—

16.1. The distribution licensee, while determining the modalities and tenure of procurement of resource mix, shall, subject to fulfilment of conditions of optimum and least cost generation procurement planning, ensure that at the initial level, available capacity within the State shall be optimized. For further optimization, procurement contract shall be decided first within the region subject to the least cost resource availability considering transmission constraints & cost of transmission for procurement from outside the region and then across regions if necessary.

16.2. In its overall power procurement planning approach, the distribution licensee shall lay greater emphasis on adequate contracting through long- & medium-term arrangements as well as on optimum utilization of generation resources in a cost-effective manner.

16.3 The distribution licensee must ensure that procurement process for the projected demand is undertaken and completed sufficiently in advance so that the procured capacity becomes available when it is required to serve the projected load. The following table gives the number of years before which procurement process will normally be completed in advance as compared to the year of projected requirement for various types of generation and types of procurement:

16.4. Assessment through Annual Rolling Plan shall ascertain incremental capacity addition requirement through long, medium or short term upon factoring in existing and planned procurement initiatives of the distribution licensee. The Plan shall also incorporate planned utilization of surplus energy contracted/proposed to be contracted to optimize the power purchase cost.

16.5. The distribution licensees shall identify the generation resource mix and procurement strategy in long-term, and short-term horizon. The distribution licensee, within 15 days of receipt from the Authority, shall file duly vetted (by the Authority) LT-DRAP, ST-DRAP along with the Annual rolling plan before the Commission for approval.

16.6 The Commission will normally approve LT-DRAP and ST-DRAP of the distribution licensees within 45 days of filing of these plans (complete in all respect) each year for the ensuring year(s) incl. annual rolling plans, as the case may be, upon taking into consideration various scenarios as well as allocation of Resource Adequacy requirement allocated to the State/distribution licensee based on its contribution to the National peak or National RA requirement as determined by Authority or the NLDC or the RLDC , as the case may be.

16.7. The distribution licensee in accordance with the orders of the Commission shall contract capacities, if any required, and submit the Annual Rolling Plan to STU/SLDC by 15th January of each year for the relevant year(s). Thereafter, within next 10 days STU and SLDC shall submit state-level aggregated plan to RLDC. enabling it to timely submit regional-level aggregated plan to NLDC

17. Optimum utilisation of contracted capacities and efficient management of surplus energy contracted.—

17.1. With an overall objective of optimizing the power purchase cost while meeting the reliability standards the distribution licensee, on best effort basis, shall engage in efficient management of surplus contracted/proposed to be contracted capacities. In order to ensure optimum and least cost generation resource procurement planning, each distribution licensee shall give due consideration to the factors such as its share in the state, regional and national coincident peak; seasonal requirement and possibility of sharing generation capacity seasonally with other States. The distribution licensee will also explore options like; capacity sharing, power banking, energy storage system, bilateral arrangement etc while preparing the Resource Adequacy plan and optimally utilize the platform for inter/intra -state capacity sharing or trading mechanism created by the Central Commission and optimize the power purchase costs as far as possible.

17.2. The distribution licensee shall submit information about contracted capacity to the SLDC and the STU for compliance verification. 17.3. The distribution licensee, shall seek approval of the Commission on the procurement plan as well as Annual Rolling Plans.

18. Monitoring and Compliance.—

18.1. Monitoring and Reporting: Based on the LT-DRAP and ST-DRAP, STU and SLDC shall communicate the state-aggregated capacity shortfall to the State Commission by 15th September of each year for the ensuring year(s) and advise the distribution licensees to commit additional capacities.

18.2. Treatment for shortfall in RA Compliance: Distribution licensees shall comply with the RA requirement as approved by the Commission. Failure of a distribution licensee to meet the approved RA requirement shall render the defaulting licensee liable for payment of non- compliance charge as determined by the Commission on case-to-case basis

Chapter- 7 Roles and Responsibilities and Timelines

19. Data Requirement and Sharing Protocol.—

19.1. Distribution licensees shall maintain and share with STU/SLDC, all data related to demand assessment and forecasting such as but not limited to consumer data, historical demand data, weather data, demographic and econometric variables, T&D losses, actual electrical energy requirement and availability including curtailment, peak electricity demand, and peak met along with changes in demand profile (e.g.: agricultural shift, time of use, etc.), historical hourly load shape, etc

19.2. Distribution Licensee shall maintain all statistics and database pertaining to policies and drivers, such as LED penetration, efficient fan penetration, appliance penetration, increased usage of electrical appliances for cooking, etc., in households, increase in commercial activities for geographic areas/regions, increase in number of agricultural pumps and solarization within control area, changes in specific energy consumption, consumption pattern from seasonal consumers such as tea plants, DSM and DERs, EVs and OA, National Hydrogen Mission, reduction of AT&C losses, etc. shall also be shared.

19.3. Distribution Licensee shall maintain at least past 10 years of statistics in its database pertaining to consumption profiles for each class of consumers, such as domestic, commercial, public lighting, public water works, irrigation, LT industries, HT industries, railway traction, bulk (non-industrial HT consumers), open access, captive power plants, insights from load survey, contribution of consumer category to peak demand, seasonal variation aspects, etc. shall also be shared.

19.4. SLDC shall maintain the licensee-specific as well as aggregate for state as whole, the statistics and database pertaining to aggregate demand assessment and forecasting data mentioned above and share state-level assessment with the Authority and the NLDC for regional/national assessment from time to time.

19.5. The distribution licensee shall share information and data pertaining to the existing and contracted capacities with their technical and financial characteristics including hourly generation profiles to with STU and SLDC for computation of state-level capacity credit factors and for preparation of state-level assessment.

19.6. SLDC and STU shall aggregate generation data and share state-level assessment with the Authority and NLDC for assessment of RA requirement.

19.7. STU shall communicate allocation of regional and national RA requirement to the distribution licensees.

20. Timelines

20.1. Distribution licensees shall submit demand forecasts to SLDC and STU by 15th April of each year for the ensuring year(s).

20.2. SLDC/STU shall aggregate and submit state-level forecasts to the Authority, the NLDC and RLDC by 15th May of each year for the ensuring year(s).

20.3. Distribution licensees shall perform LT-DRAP and ST-DRAP exercise and submit it to the Authority, STU and SLDC by 15th August of each year for the ensuring year(s).

20.4 Filing of duly vetted LT-DRAP, ST-DRAP along with proposed procurement plan, annual rolling plants etc within 15 days of receipt of LT DRAP (from the Authority) and ST-DRAP from SLDC

20.5. Submission of Annual Rolling Plan by distribution licensees to STU/SLDC by 15th January of each year.

Chapter- 8 Miscellaneous

21. Power to Give Directions.—

20.1. The Commission may from time to time issue such directions and orders as considered appropriate for implementation of these regulations.

22. Power to Relax.—

22.1. The Commission may by general or special order, for reasons to be recorded in writing, and after giving an opportunity of hearing to the parties likely to be affected, may relax any of the provisions of these Regulations on its own motion or on an application made before it by an interested person.

23. Power to Remove Difficulties.—

22.1. If any difficulty arises in giving effect to the provisions of these Regulations, the Commission may, by an order, make such provisions, not inconsistent to the provision of the Act and these Regulations, as may appear to be necessary for removing the difficulty.

24. Repeal and Savings.—

24.1 Save as otherwise provided in these regulations, the Bihar Electricity Regulatory Commission (Power Purchase and Procurement Process of Licensee) Regulations, 2018shall stand repealed from the date of commencement of these Regulations.

24.2 Notwithstanding such repeal, anything done or any action taken or purported to have been done under the repealed regulations, shall be deemed to have been doneor taken under the relevant provisions of these regulations.

By order, Sd-Illegible, Secretary, BERC.

——— PUBLISHED AND PRINTED BY THE SUPERINTENDENT, BIHAR SECRETARIAT PRESS, PATNA, BIHAR GAZETTE (EXTRA) 1798-571+10 Website:https://egazette.bihar.gov.in