THE
JHARKHAND GAZETTE
EXTRAORDINARY
PUBLISHED BY AUTHORITY
14 KARTIK 1946 (S)
RANCHI TUESDAY 5th NOVEMBER, 2024
JHARKHAND STATE ELECTRICITY REGULATORY
COMMISSION, RANCHI
--------
NOTIFICATION
23th October, 2024
Draft Jharkhand State Electricity Regulatory Commission (Framework for
Resource Adequacy) Regulations, 2024
Notification No. 105--In exercise of powers conferred under Section 61,66,86
and section181 of the Electricity Act, 2003 and all other powers enabling it in that
behalf, the Jharkhand State Electricity Regulatory Commission, hereby makes the
following Regulations.
No. 716
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Chapter 1: Preliminary
1.
Short Title, Extent and Commencement
1.1.
These Regulations may be called the Jharkhand State Electricity
Regulatory Commission (Framework for Resource Adequacy) Regulations,
2024.
1.2.
These Regulations shall come into force from April 01, 2025after
publication in the Jharkhand State Government Gazette.
1.3.
These Regulations shall extend to the State of Jharkhand.
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 and transmission resources for reliably meeting the projected
demand in compliance with specified reliability standards for serving the
load with an optimum generation mix.
2.2.
The Resource Adequacy framework shall cover a mechanism for demand
assessment and forecasting, generation resource planning, procurement
planning, and monitoring and compliance.
3.
Scope and Applicability
3.1.
These Regulations shall apply to the generating companies, distribution
licensees, State Load Despatch Centre, State Transmission Utility, and
other grid connected entities and stakeholders within the state of
Jharkhand.
4.
Definitions and Interpretation
4.1.
In this Regulation unless the context otherwise requires:
a)
‘Act’shall mean the Electricity Act, 2003(36 of 2003) and
subsequent amendments thereof.
b)
“Authority”shall mean Central Electricity Authority referred to in
sub-section (1) of Section 70 of the Act.
c)
"Capacity Credit” or “CC”shall mean a percentage of a resource’s
nameplate capacity that can be counted towards resource adequacy
requirements.
d)
"CEA RA Guidelines”shall mean Guidelines for Resource Adequacy
planning framework for India notified by Central Electricity
Authority in pursuance of Rule 16 of Electricity (Amendment) Rules,
2022.
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e)
“Commission” or “State Commission”shall mean the Jharkhand
State Electricity Regulatory Commission (JSERC) constituted under
the Act.
f)
“Expected Energy Not Served” or “EENS”shall mean the expected
amount of load (MWh) that may not be served for each year within
the time horizon for Resource Adequacy planning.
g)
“Jharkhand UrjaSancharan Nigam Limited” or “JUSNL”shall
mean the state transmission utility or STU.
h)
“Long-Term”shall
mean
duration
exceeding
five
years
for
development of demand forecasting and generation resource
planning.
i)
“Long-Term Power Procurement”shall mean procurement of power
under any arrangement or agreement with a term or duration
exceeding five years.
j)
“Long-Term
National
Resource
Adequacy
Plan”
or
“LT-
NRAP”shall mean plan for national level assessment of long-term
resource adequacy published by Central Electricity Authority as per
CEA RA Guidelines.
k)
“Loss of Load Probability” or “LOLP”shall mean probability that a
system’s load will exceed the generation and firm power contracts
available to meet that load in a year.
l)
“Medium term”shall mean five years for development of demand
forecast, generation resource plan, and procurement plan.
m)
“Medium-Term Distribution Resource Adequacy Plan” or “MT-
DRAP” shall mean plan for assessment of medium-term resource
adequacy by the distribution licensee.
n)
"Net Load”shall mean the load derived upon exclusion of actual
generation (MW) from renewable energy generation resources from
gross load prevalent on the Grid during any time-block.
o)
“Normalized Energy Not Served” or “NENS” is normalization of
the EENS by dividing it by the total system load.
p)
“Planning Reserve Margin” or “PRM”shall mean a specified
percentage of available capacity above peak demand as may be
stipulated by Authority or Commission for the purpose of generation
resource planning.
q)
“Power Exchange”shall mean any exchange operating as power
exchange for electricity in terms of the regulations issued by the
Central Electricity Regulatory Commission.
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r)
“Power Purchase Agreement (PPA)”shall mean the agreement
entered into between the Procurer(s) and the Seller pursuant to
which the Seller shall supply power to the Procurer(s) as per the
terms and conditions specified therein.
s)
“Power Sale Agreement (PSA)” shall mean the back-to-back
agreement entered into between the Buying Entity(s) and the
Intermediary Procurer/trader for onward sale of power purchased
under any power purchase agreement.
t)
“Resource Adequacy” or “RA”shall mean 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 with 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.
u)
“Short term”shall mean duration upto one year for development of
demand forecast, generation resource plan, and procurement plan.
v)
“Short-Term Distribution Resource Adequacy Plan” or “ST-
DRAP”shall mean plan for assessment of short-term resource
adequacy by the distribution licensee.
w)
“Short-Term
National
Resource
Adequacy
Plan”
or
“ST-
NRAP”shall mean plan for national level assessment of short-term
resource adequacy published by Grid India/National Load Despatch
Centre as per CEA RA Guidelines.
x)
“SLDC”shall mean the state load despatch centre of Jharkhand.
4.2.
Words and expressions used in these Regulations and not defined herein
but defined in the Act shall have the meanings respectively assigned to
them in the Act.
4.3.
All 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 Parliament/State Legislation applicable to the electricity industry in
the State shall have the meaning assigned to them in such law.
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Chapter 2: General
5.
Resource Adequacy Framework
5.1.
Resource Adequacy framework entails the planning of generation and
transmission 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 medium and short term for the purpose of these Regulations shall be
considered as:
a)
Medium term procurement plan for a period up to five years; and
b)
Short-term procurement plan for a period up to one year.
5.4.
The distribution licensee shall develop and prepare Medium-Term
Distribution Resource Adequacy Plan (MT-DRAP) and Short-Term
Distribution Resource Adequacy Plan (ST-DRAP) in accordance with the
conditions outlined under these Regulations.
5.5.
Distribution companies, State Transmission Utility, and State Load
Despatch Centre are required to share important information and data,
including forecasts of electricity demand for up to 10 years, with relevant
agencies to enable Central Electricity Authority and Grid India/NLDC to
undertake LT-NRAP and ST-NRAP studies, respectively, as per CEA RA
Guidelines.
Chapter 3: Demand Assessment and Forecasting
6.
Long-term and Medium-term Demand Forecast
6.1.
Demand assessment and forecasting is an important step for Resource
Adequacy assessment. It shall entail at least hourly, or sub-hourly as
may be decided by the Commission from time to time, assessment and
forecasts of demand within the distribution area of distribution licensee
for multiple horizons (short/medium/long-term) using comprehensive
input data and policies and drivers and scientific mathematical modelling
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.
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6.3.
The distribution licensee is required to furnish comprehensive data
regarding the consumption of electricity by various consumer categories,
such as agricultural, domestic, etc. This data is to be shared with entities
like the State Load Despatch Centre (SLDC) or State Transmission Utility
(STU) to aid in predicting the state-level demand forecast. The
distribution licensee shall submit the category wise consumption
information of pervious financial years and any other information as may
be required by SLDC/STU by April 21 of each year as per format to be
prescribed by SLDC/STU.
6.4.
The distribution licensee is responsible for establishing load forecasts for
each consumer category for which the Commission has determined
separate retail tariff.
6.5.
The distribution licensee shall determine the load forecast for a customer
category by adopting any of the following and/or combination of following
methodologies:
a)
The base 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; and
f)
econometric (specifying the parameters used, algorithm, and source
of data).
6.6.
The distribution licensee may use Electric Power Survey (EPS)
projections as base as and/or any other methodologies other than the
above-mentioned 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 Clause 6.14.
6.7.
For the purposes of deciding the load forecast for a customer category
and the methodology to be used for load forecasting of a customer
category, the distribution licensee must conduct statistical analysis and
shall select the method for which standard deviation is lowest and R-
square is highest.
6.8.
The distribution licensee shall utilize state-of-the-art tools, and
mathematical methodologies, and comprehensive database such as but
not limited scientific 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.
6.9.
The distribution licensee shall modify the load obtained on either side,
for each customer 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.
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a)
demand-side management measures;
b)
open access;
c)
distributed energy resources;
d)
DSM and 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. For each policy, a separate trajectory should be developed
for each customer category.
6.10. The distribution licensee shall take into consideration any other factor
not mentioned in clause 6.9 after recording the merits of its
consideration. Further, while undertaking demand forecasts, the
distribution licensee shall take into consideration the impact and
benefits arising out of the demand side management programmes and
DSM
plans,
energy
efficiency
measures,
energy
conservation
interventions in pursuance of JSERC (Demand Side Management)
Regulations, 2010 and amendments thereof.
6.11. The medium-term load profile of the customer 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.
6.12. The summation of energy forecast (MWh) for various consumer categories
upon suitably adjusting for captive, prosumer, and open access load
forecast, if necessary, as obtained as per clauses 6.5 to clause 6.11, as
the case may be, shall be the load forecast for the licensee.
6.13. The distribution licensee shall calculate the load forecasts (in MWh) by
adding a loss trajectory approved by the Commission in the latest tariff
order. In the 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.
6.14. 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 clause
6.13. If any other appropriate load factor is considered for future years, a
detailed explanation shall be provided.
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6.15. The distribution licensee shall conduct sensitivity and probability
analysis to determine the most probable demand forecast. The
distribution licensee must also develop long-term and medium-term
demand forecasts for 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 and Aggregation at State
7.1.
The distribution licensee shall develop a methodology for at least hourly,
or sub- hourly, as may be decided by the Commission from time to time,
demand forecasts and shall maintain a historical database.
7.2.
For the purpose of ascertaining hourly load profile and for assessment of
contribution of various customer categories to peak demand, load
research analysis shall be conducted and influence of demand response,
load shift measures, time of use shall be factored in by distribution
licensee with inputs from SLDC. 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 and drivers etc. as may be applicable
to their control area.
7.4.
The distribution licensee shall produce at least hourly, or sub-hourly as
may be decided by the Commission from time to time, 1-year short-term
(ST) and 5-year medium-term (MT) forecasts on a rolling basis and
submit to SLDC by 30th April of each year for the ensuing year(s).
7.5.
STU with inputs from SLDC and based on the demand estimates of the
distribution licensees of the State, shall estimate, in different time
horizons, namely long-term, medium term and short term, the demand
for the entire State duly considering the diversity of the State.
7.6.
SLDC shall aggregate demand forecasts by distribution licensees,
consider the load diversity, congruency, seasonal variation aspects and
shall submit state-level aggregate demand forecasts (MW and MWh) to
the Authority and NLDC and RLDC by 31st May of each year for the
ensuring year(s).
Chapter 4: Generation Resource Planning
8.
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.
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9.
Key contours and important steps in Generation Resource Planning:
9.1.
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 within control area (state/distribution licensee).
9.2.
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 and medium term.
9.3.
The mapping shall include critical characteristics and parameters of the
generating machines, such as heat rate, auxiliary consumption, ramp-up
rate, parameters ramp-down rate, etc, for thermal machines; hydrology
and of 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. Some of
important parameters that would be considered for characteristic
assessment shall include but not limited to following:
a)
Name of the plant (with location, district, taluka, geo-coordinates)
b)
Installed Plant Capacity (MW) (existing and planned)
c)
Heat rate of thermal generating stations
d)
Auxiliary consumption (MW)
e)
Maximum and Minimum generation limits (MW)
f)
Ramp up and Ramp down rate (MW/min)
g)
Minimum up and down time
h)
Plant availability factor (%)
i)
Average capacity utilisation factor for past 3 years (%)
j)
Historical outage rates and planned outage rate
k)
Installed Capacity and generation profile of renewable energy
generation resources
l)
Under-construction / contracted capacity with likely date of
commissioning
m)
Planned Retirement of capacity or Renovation of capacity with
timelines
n)
Transmission expansion plans with timelines
o)
Evacuation
arrangements
with
timelines
for
RE
generation
resources
9.4.
Constraints such as penalties for unmet demand, forced outages,
spinning reserve requirements, and system emission limits as defined in
State and Central electricity grid codes, planning criteria of CEA and
emission norms specified by the Ministry of Environment and Forest
shall be identified and enlisted.
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9.5.
The distribution licensee must create a comprehensive map of all its
current, future, and retiring resources, representing their capacity in
megawatts (MW). This map serves as a valuable tool for long-term and
medium-term power procurement planning purposes.
9.6.
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 with proper justification, which
will be subject to approval by the Commission. The value of planning
reserve margin considered shall be stipulated in the resource plan along
with justifications.
10. Capacity Crediting of Generation Resources
10.1. The distribution licensee shall compute Capacity Credit (CC) factors for
their contracted generation resources by applying the net load-based
approach as outlined under Clause 10.2 of this Regulation. The five-year
average of the Capacity Credit (CC) factor for each type of the contracted
generation resource for the recent five years on a rolling basis shall be
considered as Capacity Credit factor for the purpose of generation
resource planning.
10.2. The Net Load based approach/methodology for determination of Capacity
Credit (CC) factors for generation resources (including wind and solar)
shall be adopted as under:
a)
For each year, the hourly recorded Gross Load for 8760 hours (or
time- block) shall be arranged in descending order.
b)
For each hour, the Net Load is calculated by subtracting the actual
wind or solar generation corresponding to that load for 8760 hours
(or time-block) and then arranged in descending order similar to
Step 1.
c)
The difference between these two load duration curves represents
the contribution of capacity factor of wind generation or solar
generation, as the case may be.
d)
Installed capacity of wind or solar generation capacity is summed up
corresponding to the top 250 load hours.
e)
Total generation from wind or solar generation corresponding to
these top 250 hours is summed up.
f)
Resultant CC factor is (Total Generation for top load 250 hours)/
(Installed RE Capacity for top load 250 hours), as per formula below:
CC factor =
ࡿ࢛ ࢌ ࡾࡱ ࡳࢋࢋ࢘ࢇ࢚ ࢌ࢘ ࢚ ࢞ ࢎ࢛࢙࢘
ࡿ࢛ ࢌ ࡾࡱ ࢇࢇࢉ࢚࢟ ࢌ࢘ ࢚ ࢞ ࢎ࢛࢙࢘
g)
The process for CC factor determination shall be undertaken for
each year for duration of past five-years and the resultant CC is the
average of CC values of past 5 years.
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10.3. 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. For this purpose, CC factors as specified by Authority or the
Commission shall be considered.
10.4. CC factors for hydro generation resources shall be computed based on
water availability with different CC factors for run-of-the-river hydro
power projects and dam-based/storage-based hydro power projects. CC
for thermal resources shall be computed based on coal availability and
forced outages.
10.5. The distribution licensee shall share CC factors for their contracted
resources along with justification for its computations with SLDC.
10.6. SLDC shall calculate state-specific CC factors considering the aggregate
State Demand and State Net Load and contracted RE generation
resources available in the State and shall submit such CC factor
information to the Authority and NLDC and RLDC from time to time.
11. Assessment of Planning Reserve Margin (PRM)
11.1. 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.
11.2. Such Planning Reserve Margin (PRM) factor (for example, 10%) shall be
based on the reliability indices in terms of Loss of Load Probability
(LOLP, for example, 0.2%) and Normalized Energy Not Served (NENS, for
example, 0.05%) as may be specified by the Authority or separately
computed by the distribution licensee and STU/SLDC at state level,
subject to approval of by Commission, and the same shall be considered
by entities in their planning for resource adequacy requirement and
generation resource capacity planning.
11.3. 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.
12. Ascertaining Resource Adequacy Requirement and its Allocation
for Control Area
12.1. Upon applying CC factors as determined under Regulation 10 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 at least one
hour, or 15-minute interval or as may be decided by the Commission
from time to time, but not more than one hour, shall form the resource
map of the distribution licensee.
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12.2. The distribution licensee shall subtract the resource map developed in
clause 12.1 from the demand forecast developed in section 6 (ref. Clause
6.14) to identify the resource gap. The resource gap in terms of RA
compliance for the distribution licensee for the long term and medium
term shall be developed in the manner as specified in these Regulations.
12.3. The distribution licensee shall conduct sensitivity and probability
analysis to determine the most probable resource gap. The distribution
licensee shall also develop long-term and medium-term resource gap
plans for possible scenarios, while ensuring that at least three different
scenarios (most probable, business as usual, and aggressive) are
developed.
12.4. Based on most probable scenario, the distribution licensee shall
undertake development of Medium-term Distribution Resource Adequacy
Plan (MT-DRAP) and Short-term Distribution Resource Adequacy Plan
(ST-DRAP) exercise by 31st August of each year to meet RA target
requirement.
12.5. Long-term National Resource Adequacy Plan (LT-NRAP) and Short-term
National Resource Adequacy Plan (ST-NRAP) reports shall act as
guidance for the distribution licensee(s) for undertaking the Resource
Adequacy exercises.
12.6. The Central Electricity Authority will release the Long-term National
Resource Adequacy Plan (LT-NRAP) to establish the optimal Planning
Reserve Margin (PRM) needed nationally to meet reliable supply targets.
This report will also outline the most effective generation mix for the next
10 years, ensuring compliance with Resource Adequacy Requirements
while meeting national demand at the lowest cost. Additionally, it will
detail capacity credits for various resource types at the national level and
define each state's contribution toward meeting the national peak
demand.
12.7. NLDC will release a one year look ahead Short-term National Resource
Adequacy Plan (ST-NRAP) encompassing key parameters such as
demand forecasts, resource availability considering ongoing construction
of new projects, planned maintenance for existing stations, historical
forced outage rates station-wise, and plans for decommissioning.
12.8. Based on the allocated share in national peak provided in LT-NRAP for
the State, STU/SLDC shall allocate each distribution licensee’s share in
the state peak within 15 days of the publication of LT-NRAP based on
average of the percentage share in the state coincident peak demand and
percentage share in the state non-coincident peak demand.
12.9. The distribution licensee based on the above allocation shall accordingly
plan to contract the capacities to meet their Resource Adequacy
Requirement (RAR) while ensuring that their own peak demand plus
Planning reserve margin is met.
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12.10. The distribution licensee shall keep minimum 70% long termcontracts,
minimum 20% Medium-term contracts, and the rest to be met through
Short-term Long-term contracts.
12.11. The contracts mix mentioned under Regulation 12.10 of these
Regulations may be periodically reviewed by the Commission.
12.12. Provided that power procurement through Day-Ahead Market (DAM),
shall not be considered towards the contribution for meeting Resource
adequacy requirement.
12.13. RA requirement planning of the state shall be done with reference to
national coincident peak and of distribution licensees with reference to
average of share in state coincident peak and share in state non-
coincident peak, to optimize requirement of incremental capacity
addition through annual rolling plan. Mid- term review of state RA
requirement planning shall be conducted to check for events of slippages
by states, if any.
12.14. While planning RA requirement, the distribution licensee shall duly
factor in the allocation of RA requirement to the distribution licensee as
may be suggested by theSTU/SLDC, as the case may be, based on
average of share in state coincident peak and share in state non-
coincident peak for MT-RA and ST-RA.
12.15. The Commission shall approve MT-DRAP and ST-DRAP of the
distribution licensees by September 30 of 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/state peak respectively as determined
by Authority/NLDC/RLDC and STU/SLDC, as the case may be.
Chapter 5:Power Procurement Planning
13.
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 the capacity trading or sharing to minimize risk of
resource shortfall and to maximize rewards of avoiding stranded
capacity or contracted generation.
14. Procurement Resource Mix
14.1. The distribution license in its power procurement strategy shall identify
an optimal procurement generation resource mix that shall enable
smooth RE integration in its portfolio of power procurement resource
options while meeting reliability standards.
14.2. For identification of the optimal generation procurement resource mix,
optimization techniques and least-cost modelling shall be employed in
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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 Commission for approval.
14.3. 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.
14.4. The power capacity procurement from renewable energy sources for
fulfilling the RPO targets shall be carried out as per JSERC (Renewable
Energy Purchase Obligation and its Compliance), Regulations, 2016 and
amendments thereof.
14.5. The power procurement from Wind, Solar PV, Wind Solar Hybrid, Round
the Clock (RTC) generations shall be carried out as per the guidelines for
tariff based competitive bidding process notified by the Ministry of Power.
14.6. The distribution licensee shall contract storage capacity corresponding to
the results of MT- DRAP capacity addition requirement for future years
from Battery Energy Storage System (BESS) and Pump Storage Projects
(PSP) as per the guidelines for tariff based competitive bidding process
notified by the Ministry of Power.
14.7. The distribution licensee may contract power through Central Agencies
Intermediaries / Traders / Aggregators / Power Exchanges or through
agreements / Banking arrangements with other distribution licensees in
compliance with competitive bidding guidelines.
14.8. The distribution licensee may procure power on Short-term and Medium-
term basis through DEEP, PUSHP portal, and over the Counter (OTC)
platforms.
15. Procurement Type and Tenure
15.1. The distribution licensee, while determining the modalities and tenure of
procurement of resource mix, shall ensure that at the initial level,
available capacity within resource the state shall be optimized. For
further optimization, procurement contract shall be decided first within
the state subject to the least cost availability considering transmission
constraints of transmission for procurement from outside the state and
then across states if necessary.
15.2. The distribution licensees shall identify the generation resource mix and
also procurement strategy in long term, medium-term and short-term
horizon and seek approval of the Commission.
15.3. The distribution licensee shall demonstrate to the Commission 100% tie-
up for the first year and a minimum 90% tie-up for the second year to
meet the requirement of their contribution towards meeting state peak.
Only resources with long / medium / short-term contracts shall be
considered to contribute to the Resource adequacy requirement.
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Jharkhand Gazette (Extraordinary), Tuesday, 5th November, 2024
15.4. For subsequent three years, the distribution licensee shall also furnish a
plan to meet estimated requirement of their contribution to meet state
peak for the Commission’s approval.
15.5. The MT-DRAP shall be carried out by the distribution licensee on an
annual rolling basis considering the contracted capacity as a part of the
system and shall optimize for additional capacity required.
15.6. The distribution licensee through MT-DRAP, shall demonstrate to the
Commission their plan to meet their Peak demand and energy
requirement with a mix of Long-term, Medium-term, and Short-term
contracts. Provided that the distribution licensee shall keep the share of
contracts in the range as mentioned under Regulation 12.10 of these
Regulations.
15.7. Assessment through Annual Rolling Plan shall ascertain incremental
capacity addition requirement through MT/ST upon factoring in existing
and planned procurement initiatives of the distribution licensee.
15.8. The distribution licensee shall contract capacities by 30thNovember of
each year and submit the Annual Rolling Plan to STU/SLDC by
31stDecember of each year for ensuring year(s).
15.9. STU and SLDC shall submit state-level aggregated plan to RLDC and
RLDC shall submit state-level aggregated plan to NLDC by 31 January of
each year for the ensuing year(s).
16. Sharing of Capacity
16.1. The distribution licensee shall duly factor in the possibility of short-term
capacity sharing while preparing the Resource Adequacy plan and
optimally utilize the capacity available within the state through
competitive sharing arrangements or other mechanisms, and then use
the platform for inter-state capacity sharing or trading mechanism if
created by the Central Commission or other mechanisms as the case
may be, and optimize the capacity costs as far as possible.
16.2. The distribution licensee shall submit information about contracted
capacity to the SLDC and the STU for compliance verification.
16.3. The distribution licensee, the STU and the SLDC shall seek approval of
the Commission to the procurement plan as well as Annual Rolling
Plans.
17. Approval of Power Purchase Agreement
17.1. Any new Capacity arrangement/tie-up shall be subject to the prior
approval of the Commission in view of necessity, reasonableness of cost
of power purchase and promotion of working in an efficient, economical
and equitable manner.
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Jharkhand Gazette (Extraordinary), Tuesday, 5th November, 2024
17.2. All procurement of Long/Medium/Short-term power from various
sources
shall
carried
out
as
per
the
Guidelines/Rules/Regulations/Policies
issued
by
the
Central
Government/Appropriate Commission from time to time.
17.3. Any new power purchase agreement for Long/Medium-term or
amendments to existing Long/Medium-term Power Purchase Agreement
(PPA’s)/ Power Sale Agreement (PSA) entered into by the distribution
licensee shall be subject to the prior approval of the Commission.
17.4. The distribution licensee shall submit the list of all existing Power
Purchase Agreements executed with different conventional power plants
as well as RE Generators along with the Resource Adequacy plan.
18. Variation in Power Purchase
18.1. The distribution licensee may undertake additional power procurement
during the year, over and above the approved resource adequacy
procurement plan on account of following exemptions:
a)
In case, where there has been an unanticipated increase in the
demand for electricity or a shortfall or failure in the supply of
electricity from any approved source of supply during the year or
when the sourcing of power from existing tied-up sources becomes
costlier than other available alternative sources, the distribution
licensee may enter into additional agreement for procurement of
power.
b)
The distribution licensee may enter into a Short-term arrangement
or agreement for procurement of power when faced with emergency
conditions that threaten the stability of the grid, or when directed to
do so by the SLDC/RLDC to prevent grid failure or during exigency
conditions and for banking with other States on Short-term basis
without prior approval of the Commission.
c)
Provided that the details of such Short-term procurement shall be
submitted to the Commission within 45 days from date of
procurement of power.
Chapter 6: Monitoring and Compliance
19. Monitoringand Compliance
19.1. Monitoring and Reporting: Based on the MT-DRAP and ST-DRAP, STU
and SLDC shall communicate the state-aggregated capacity shortfall to
the Commission by 15thSeptember of each year for the ensuring year(s)
and advise the distribution licensees to commit additional capacities. The
Commission shall approve RA plans by 30th September of each year.
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Jharkhand Gazette (Extraordinary), Tuesday, 5th November, 2024
19.2. Treatment for shortfall in RA Compliance: Distribution licensees shall
comply with the RA requirement and in case of non-compliance,
appropriate non- compliance charge shall be applicable for the shortfall
for RA compliance.
19.3. For shortfall in RA compliance, SLDC shall levy and collect non-
compliance charge from the concerned Distribution Licensee.
19.4. The rate of Non-compliance charges shall be equivalent to 1.1 times the
Marginal Capacity Charge (Rs/kW/month) or 1.25 times the Average
Capacity Charge (Rs/kW/month) whichever is higher, as approved by the
Commission for the power procurement by concerned distribution
licensee under its ARR/Tariff Order for the relevant financial year unless
separately specified by the Commission. However, at this stage, the
Commission waives these penalties, and these shall become applicable
from April 01, 2026.
19.5. The distribution licensee shall not be allowed to recover such non-
compliance charge as part of its ARR.
Chapter 7: Roles and Responsibilities and Timelines
20. Data Requirement and Sharing Protocol
20.1. 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.
20.2. Distribution licensee shall maintain all statistics and database pertaining
to policies and drivers, such as LED penetration, efficient fan
penetration, appliance penetration, demand side management and
energy efficiency measures, 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.
20.3. 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.
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Jharkhand Gazette (Extraordinary), Tuesday, 5th November, 2024
20.4. 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 national assessment
from time to time.
20.5. 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.
20.6. SLDC and STU shall aggregate generation data and share state-level
assessment with the Authority and NLDC for assessment of RA
requirement.
20.7. STU shall communicate allocation of regional and national RA
requirement to the distribution licensees.
21. Timelines
21.1. Distribution licensees shall submit demand forecasts to SLDC by April
30 of each year for the ensuring year(s).
21.2. SLDC shall aggregate and submit state-level forecasts to the Authority
and the NLDC by 31st May of each year for the ensuring year(s).
21.3. Distribution licensees shall perform MT-DRAP and ST-DRAP exercise by
31st August of each year for the ensuring year(s).
21.4. STU and SLDC shall communicate the state-aggregated capacity shortfall
to the Commission by 15th September of each year.
21.5. The Commission shall approve RA plans by 30th September of each year.
21.6. STU and SLDC shall submit state-level aggregated plan to NLDC by
January of each year.
22. Publication of the information on website
22.1. The monthly/weekly/day-ahead/intraday power procurements/sale the
distribution licensee and generator schedule shall be made available on
the websites by of the distribution licensees and SLDC within 45 days of
such procurements/sale with ease of access to the current as well as
archived data.
22.2. SLDC shall also publish the monthly Merit Order Dispatch (MoD) stack
along with per unit variable cost of each generating station on its
website.
23. Constitution of dedicated cells by Distribution Licensee
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Jharkhand Gazette (Extraordinary), Tuesday, 5th November, 2024
23.1. The Distribution Licensees shall establish a planning cell for Resource
Adequacy within three months of the Regulation coming into force. The
cell shall have the requisite capability and tools for demand forecast,
capacity, RE integration etc.
23.2. Another round the clock dedicated cell shall also be constituted by
Distribution Licensees for power purchase/sell in real-time, and also
undertake intra-day, day- ahead, week ahead power procurement
through Power Exchanges or any other means. Distribution Licensees
shall frame suitable guidelines for the modus operandi of the dedicated
cells in line with the spirit of these Regulation and shall apprise the
Commission for the same within 45 days from the date of coming into
force of this Regulations.
23.3. The distribution licensee shall make the Resource Adequacy Plan in
consultation with Sector State Sector Generating Companies, other
Distribution Licensees, Central Generating Companies, Transmission
Companies, National / Regional /State Load Dispatch Centres, and
Central Electricity Authority. It may also make enquiries with the
Trading Companies and States with surplus power to estimate the likely
availability and price of power across the country for peak, off-peak and
normal periods.
Chapter-8: Miscellaneous
24. Inherent Powers of the Commission
24.1. Nothing in these Regulations shall be deemed to limit or otherwise affect
the power of the Commission to make such orders as may be necessary
to meet the ends of justice.
24.2. Nothing in these Regulations shall bar the Commission from adopting in
conformity with provisions of the Act, a procedure which is at variance
with any of the provisions of these Regulations, if the Commission, in
view of the special circumstances of a matter or a class of matters, deems
it just or expedient for deciding such matter or class of matters.
24.3. Nothing in these Regulations shall, expressly or implied, bar the
Commission from dealing with any matter or exercising any power under
the Act for which no Regulations have been framed, and the Commission
may deal with such matters, powers, and functions in a manner, as it
considers just and appropriate.
25. Interpretation
25.1.
The decision of the Commission regarding the interpretation of these
Regulations shall be final and binding.
26. Power to amend
20
Jharkhand Gazette (Extraordinary), Tuesday, 5th November, 2024
26.1. The Commission may from time to time add, vary, alter, modify or amend
any provisions of these Regulations after following the necessary
procedures.
27. Power to remove difficulties
27.1. If any difficulty arises in giving effect to any of the provisions of these
Regulations, the Commission may, by a general or special order, not
being inconsistent with the provisions of these Regulations or the Act, do
or undertake to do things or direct to do or undertake such things which
appear to be necessary or expedient for the purpose of removing the
difficulties.
28. Power to relax
28.1. The Commission may by general or specific 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 the
affected party.
By Order of the Commission
Sd/-
Secretary
Jharkhand State Electricity Regulatory Commission
Jharkhand Gazette (Extraordinary), Tuesday, 5th November, 2024 21
Annexure-I: Data Requirement Templates
Data template for demand forecasts for state and its distribution licensees as following:
Demand Forecast (Summary Statement for State and All DISCOM:s separately) - Discom wise (Name of Discom:___)
S.No
Particulars
Actual of Previous Years
Current
Year (n)
YoY growth rate/CAGR as
applicable (%)
Projections
Yr(n-1)
Yr(n-2)
Yr(n-3)
Yr(n+1)
Yr(n+2)
..Yr(n+10)
1
Energy Sale(MUs)(Consumer category wise as per Retail
Supply Tariff Order)
Domestic
Commercial
LTIS
IAS
HT
HTS
HTSS
HT Institutional
SS
2
Total Energy Sale (MU)- (Cumulative of all consumer
categories excluding Open Access Sales)
3
Total Energy Sale (MU)- (Cumulative of all consumer
categories including Open Access
sales
4
YoY growth rate for total energy Sales (%) (excluding 0-4)
5
YoY growth rate for total energy Sales (%) (including 04)
6
Distribution losses - in %
7
Distribution losses - in MU
22
Jharkhand Gazette (Extraordinary), Tuesday, 5th November, 2024
Demand Forecast (Summary Statement for State and All DISCOM:s separately) - Discom wise (Name of Discom:___)
S.No
Particulars
Actual of Previous Years
Current
Year (n)
YoY growth rate/CAGR as
applicable (%)
Projections
Yr(n-1)
Yr(n-2)
Yr(n-3)
Yr(n+1)
Yr(n+2)
..Yr(n+10)
8
Supply/Requirement at DISCOM Boundary (MU)
9
Intra-State Transmission losses - in %
10
Intra-State Transmission losses - in MU
11
Supply/Requirement at State Boundary (MU)
12
Inter-State Transmission losses - in %
13
Inter-State Transmission losses - in MU
14
Ex-Bus Requirement of DISCOM (MU) (excluding OACs,
Railways) - RESTRICTED|
15
Sale by SLDC to SEZ (as applicable)
16
Energy Wheeled for Railways/OA Consumers (as
applicable)
17
Ex-Bus Requirement of DISCOM (MU) (including OA,
Railways) -RESTRICTED
18
Unsupplied energy due to system constraints (MU)
19
Ex-Bus Requirement of DISCOM (MU) (excluding OA,
Railways) - Unrestricted
20
Ex-Bus Requirement of DISCOM (MU) (including OA,
Railways) - Unrestricted
21
System Load Factor
22
Peak load of DISCOM (MW) (excluding OA, Railways)
23
Peak load of DISCOM (MW) (including OA, Railways)
23
Jharkhand Gazette (Extraordinary), Tuesday, 5th November, 2024
Data template for historical load, RE installed capacity, and RE generation data in hourly resolution as following:
Year
Month
Day
Hour
Load(MW)
Solar IC(MW)
Solar Gen (MW)
Wind IC (MW)
Wind Gen (MW)
Hydro IC
(MW)
Hydro
Gen
(MW)
Data template for technical and financial characteristics of each generating station as following:
S.N
o
Generating
Stations
Resource
Type
Installed
Capacity
( MW)
Allocated
Capacity
(MW)
Commissio
ning Year
Expected
Retiremen
t Year
Fixed
Cost(Rs/k
W/Yr)
Variable
Cost(Rs/k
Wh)
Heat
Rate
(at
full
load)
Ramp
Rate(Mw/m
in)
Start
up
cost
(Rs)
Start
up
time
(H)
Planned
Maintena
cne
Forced
Outag
e
PLF
(%)
Date of
Signing
of PPA
Date of
expiry
of PPA
1
Central
Generating
Station
2
State
Generating
Station
3
Hydro
4
Renewable
5
IPP
Data template for peak demand and energy requirement projections of all Discoms :
24
Jharkhand Gazette (Extraordinary), Tuesday, 5th November, 2024
Source
Discom1
Discom2
Consumer1
Consumer2 etc
Unit
MUs
Peak MW
MUs
Peak MW
MUs
Peak MW
MUs
Peak MW
Yr1
Yr2
Yr3
….
….
Yr10
---------
Printed & Published by the Superintendent of Jharkhand Government Press, Doranda, Ranchi.
Jharkhand Gazette (Extraordinary) 716-- 50.