CDM-PDD-FORM
Project design document form for
CDM project activities
(Version 06.0)
Complete this form in accordance with the Attachment “Instructions for filling out the project design document form
for CDM project activities” at the end of this form.
PROJECT DESIGN DOCUMENT (PDD)
Title of the project activity
HAWA Energy (Pvt) Ltd 49.3 MW Wind Power Project in
Jhimpir, Sindh Pakistan
Version number of the PDD
01
Completion date of the PDD
2 May, 2016
Project participant(s)
Renewable Stars (Pvt.) Ltd.
Host Party
Pakistan
Sectoral scope and selected
methodology(ies), and where applicable,
selected standardized baseline(s)
Scope 1: energy industries (renewable- / non-renewable
resources)
Applied methodology: ACM0002 (version 16)
Estimated amount of annual average GHG
101,727 t CO2per year
emission reductions
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SECTION A. Description of project activity
A.1.
Purpose and general description of project activity
HAWA Energy (Pvt) Ltd, have registered office with Securities & Exchange Commission Pakistan
(SECP) and is located at 68, Nazimuddin Road, Islamabad, Pakistan. HAWA Energy (Pvt) Ltd opted to
invest in a Wind Power Project of 49.3 MW installed capacity and to accept the current upfront
tariff announced by NEPRA for wind power projects valid till September 2016. The project shall be
executed in Independent Power Producer (IPP) mode. .
The total installed capacity of HAWA Energy Wind Farm would be 49.3 MW. The Project will install
29 units of General Electric-103 turbine generators (WTGs), each with rated output of 1.7MW.
Main construction activities of the Project are the foundations of the 132kV substation, wind
turbine generators (WTGs) and Air Insulated Outdoor Sub-Station. The earthquake basic intensity
of this Project is 7 on the Richter scale. The construction period of the project is 16 months
It is estimated that the project activity will supply the annual benchmark Net Energy output of
180,687MWh/annum of clean electricity to the Pakistani national electricity grid resulting in a net
load factor of 41.253% and 4370hrs as the average operation hours per year. The HAWA Wind
Power Project will also include the construction of a new on-site substation and a 132 kV
transmission line, which will transmit generated electricity to the Pakistani national electricity grid.
Since, the project activity includes installation of a new grid-connected renewable power plant,
therefore, the project is corresponding to sectoral scope 1: Energy industries (renewable- / nonrenewable sources) and applies the approved large-scale methodology ACM0002 (version 16). The
baseline scenario is therefore:
“Retrofit, rehabilitation (or refurbishment), replacement or capacity addition of an existing power
plant or construction and operation of a new power plant/unit that uses renewable energy sources
and supplies electricity to the grid.”
National Electric Power Regulatory Authority (NEPRA) in Pakistan has forecasted that, in 2030,
Pakistan’s peak demand will be around 113,695MW1. The Installed capacity of Pakistan as on 30th
June, 2014 was 23,636 MW; of which 15,887 MW (67.22%) was thermal, 6893 MW (29.16%) was
hydroelectric, 750 MW (3.17%) was nuclear and 105.9MW(0.45%) was wind. Further information
regarding the existing and planned power plants is given in section B.4
Pakistan’s major electricity sources are thermal and hydro generation. The wind energy sector of
Pakistan has matured in the last couple of years. The major impediments delaying the
development of wind power projects have been removed. Wind data of more than 5 years is
available for two locations, i.e. Gharo and Jhimpir. All the stakeholders are now at the same
frequency and are fully motivated to facilitate the development of wind power in the country.
Baseline scenario is considered as the scenario existing prior to the start of implementation of the
project activity. The project activity will achieve CO2 emission reductions by replacing electricity
generated by fossil fuel powered plants connected to the national electricity grid. The project is
expected to achieve annual emission reductions of about 101,727 tCO2e/ year. The implementation
1Integrated
Energy Plan2009-2022, Ministry of Finance GOP
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of this project is expected to contribute to sustainable development in Pakistan in various ways,
including:

The project is expected to provide reliable electricity to the national electricity system. This is in
line with Pakistan’s Vision 2025, which recognizes reliable and cheap energy as one of the
foundations for economic growth and essential for making Pakistan among top 25 large economies
of the world by 20252

The project is expected to provide local employment opportunities during the construction and
operation phase.

The project is expected to contribute towards attracting foreign direct investment.

The project will improve the hydrocarbon trade balance through reduction of oil imports used for
electricity generation.

The project will have a positive impact on the transfer of wind energy technology to Pakistan, as
well as know-how skills of local workers. The transfer of technology and know-how will be directly
replicable to other future wind energy projects.

The project will reduce the consumer price of electricity.
A.2.
Location of project activity
A.2.1. Host Party
The host country is Islamic Republic of Pakistan. Pakistan ratified the Kyoto Protocol on 1st April 20053 . The
Designated National Authority in Pakistan is Ministry of Climate Change.
A.2.2. Region/State/Province etc.
Sindh Province
A.2.3. City/Town/Community etc.
Jhampir, District Thatta
A.2.4. Physical/Geographical location
The wind farm 49.3 MW of HAWA Energy Pakistan Private Limited (hereinafter called HAWA Wind Farm) in
Jhimpir, Sindh Province, is located near the Jhimpir Village of Sindh, about 115 km from Karachi, the largest
port and industrial city of Pakistan and about 80km from the coastline of the Arabian Sea. The geographical
location of the project is shown in Figure-1 below:
2Government
of Pakistan, Ministry of Planning, Development and Reforms
3Government
of Pakistan, Climate Change Division
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Figure 1 Geographical Location of Project
Following are the land coordinates:
Table 1:1200 Acres Land351 Acres Land GPS Coordinates
25°15'19.22"N
67°58'42.83"E
25° 9'38.09"N
68° 1'38.21"E
25°15'17.74"N
67°58'28.60"E
25° 9'34.06"N
68° 1'35.26"E
25°12'43.28"N
67°58'56.18"E
25° 6'45.93"N
68° 6'17.70"E
25° 9'46.48"N
25° 9'56.81"N
68° 1'39.17"E
68° 1'49.76"E
25° 6'41.46"N
68° 6'15.51"E
25°12'50.42"N
67°59'08.97"E
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Figure 2 Land Coordinates of HAWA Wind Farm
A.3. Technologies and/or measures
A.3.1 Project Overview
The total installed capacity of HAWA Energy Wind Farm would be 49.3MW and the project shall use a total
of 29 WTGs of General Electric GE 1.7-103. Two132kV step-up substation and one monitoring centre will be
built. The construction period is 18 months.
The locality enjoys a flat terrain, scarce plant cover with little vegetation, savanna being the mostly
observed. There are some very small and scattered pieces of agricultural lands. The area has dry climate.
The project location is rich in wind energy potential with very good annual average wind speeds. It has a
good access to major highways and adequate power grid infrastructure to evacuate power, thus rendering
itself an appropriate location for large wind power stations. The Project site is consisted of 1551acres. The
satellite map of Project Site is shown in Figure 3 below: The terrains are flat at the Project Site
Figure 3: HAWA Wind Project Site Layout
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A.3.1.2 Wind Regime in Jhimpir and Metrological Stations
Located on the western stretch of the South Asian Continent, the Islamic Republic of Pakistan is largely
under the influence of tropical desert climate. The thermal depression of South Asia and the monsoon
winds shape Pakistan’s southern coastal areas and northern mountain areas into a land rich in wind
resources. The coastal areas refer to Southern Sindh and the vast plateau to the east and the west to
Karachi city.
Figure 4: Distance of Project Site from Karachi
Figure-5 below indicates the bearing of the HAWA wind farm site with regards to the wind map of Pakistan.
This shows that the HAWA wind farm site is located at one of the best suited locations for wind power
development in Pakistan.
HAWA Wind Power Project
Location
Figure 5: Wind Map of Pakistan provided by by NREL
There are number of wind power projects being commercially operated, installed and under development
within the vicinity of the Hawa Wind Project, mainly towards northeast and southwest of the project area.
In total, more than 19 wind farms are planned with in the wide-ranging surrounding.
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Figure 6: HAWA project layout with existing units
A.3.1.3 Wind Resource Assessment
For the wind resource assessment and wind farm energy yield calculation of HAWA Energy Private Limited
(HEPL), measured data from two wind measurement systems were used.
Table 2: Overview of Measurement Campaign of Met Mast
No.
Name
1
2
HAWA
Yunus
Height
a.g.l [m]
80
85
Altitude
a.s.l. [m]
89
55
Easting
Northing
UTM z42, WGS84
397,240
2,792,310
398,826
2,780,111
Measurement Period
Start
End
25.09.2012 10.09.2015
24.11.2008 02.10.2013

The wind data of the met mast HAWA located in the north east part of the old HAWA wind farm.
The met is approx. 8km from the nearest WTG of the new planning. Out of the 3 years measured
period from 09.2012-09.2015, a 12 month period could successfully reconstructed.

The data of the wind met mast Yunus, which is located in the neighboring wind farm approx. 5km
from the WTG of the new planned HAWA wind farm, has also been made available for the
assessment. The data comprises a period from 11.2008 to 10.2013 and 48 month of data could be
reconstructed successfully.
Comparing both elaborated data sets, it is noted that the HAWA met mast data is supporting the results of
the Yunus measurement. Because the Yunus data provides less uncertainty, longer data period and slightly
better spatial relation with the new HAWA project, the Yunus wind data has been selected for the wind
resource assessment.
Wind Measurement Mast at Yunus
The 85 m high Yunus wind measuring mast was installed in November 2008. The mast is of lattice structure
with triangular cross section having side width of approx. 2 ft (61 cm). The mast is located at a distance of
approx. five (5) km from the Project site
The wind speed at Yunus mast is recorded by five (05) Thies First Class anemometers installed at heights of
85, 60, 30 and 10 m above ground level. The data from the mast was collected using data logger
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Directional Correction
Direction frequency distribution is checked and compared with MERRA data during common measurement
period. As mentioned above an offset of -8° is applied on wind direction data. The sector wise frequency
distribution before and after correction is shown in figure:
Figure 7: Directional correction at 83.5 m (Yunus Mast)
All sensors are checked for functionality in the same pattern and no abnormal behaviour has been
observed.
A general finding of the analyses is that the long term wind speed is higher than the measured wind speed
(7.76 m/s at 85m a.g.l.). The 10 years long term period is considered as most reliable. The weighted average
of the two best correlating reference points (EmdERA_N25.6_E068.2 and MERRA_68.0E, 25.0N) has been
used, weighted by the R2 values. The EmdERA N25.6_E68.2 data set provided best fitting (R²) while the
MERRA data set provides good fitting and is nearer to the site and showing a more conservative trend. Thus
a long term wind speed of 7.88 m/s is calculated. Compared to the measured wind speed value of 7.76 m/s
in 85m height, this represents a scaling factor of 1.015 used for all measured wind speeds to represent the
long-term wind conditions on site.
The standard software package WindPRO (ver2.9)/ WAsP (ver. 11) are used for the flow modelling and
energy generation assessment.
Wake Decay Constant
The wind farm is consisting of 29 wind turbines in case of GE1.7-103 and 24 in case of Gamesa G114-2.1
sited within the wind farm. There are influences of the up-wind turbines related to wind and turbulence
conditions within wind farm. This wake effect on each other is considered in the energy yield calculation.
There are also several neighboring wind farms with approx. 500 WTG, making the whole Jhimpir area a
wind energy region. To evaluate the impact of other turbines, neighbouring wind farms in radius of 30km
are modelled in WAsP.
For the model validation, the wind shear profile measurement at Yunus mast at heights of 85 m and 60 m is
compared to the model calculated wind shear. The model background roughness classes are determined on
the experiences of the assessor as well as on the observed landscape. The roughness classes, arrangement
and distributions used in the model are ruling the wind shear in the model. The model wind shear of 0.12 is
confirmed by the measured value.
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Neighboring wind farms
Neighboring wind farms are influencing the yield of the HAWA wind farm. The wake effects of the turbines
in upwind side of HAWA wind farm are reducing the yield expectation. Wind farms in a radius of 30km have
been considered in the study, in two scenarios:
Scenario 1: Wind farm projects operating or in an advanced development or construction phase in the
vicinity of the HEPL Project site. In this scenario 474 neighbouring wind turbines have been considered and
calculated
Scenario 2: Additional to the WTGs of Scenario 1, wind farm projects in the 30km radius are considered
which are considered likely to be developed within the next few years.
Air density at Project Site
Temperature and air density information have been derived for each turbine position applying the
barometric formula. It is based on long term correlated average temperature of approximately 26.9°C
measured on site. The air density is in range of 1.151 kg/m³ to 1.162 kg/m³ at the turbine positions
considering total height above sea level (altitude + hub height). The power curve at each turbine position is
adapted accordingly following an IEC modified method implemented in WindPRO.
Classification according to wind speed
Wind turbines are classified according to the following extreme 10 minute wind speed in a recurrence
period of 50 years, referred to as reference wind velocity Vref .
Table 3: WTG Classes according to IEC61400-1 Ed. 3
I
II
III
WTG Classes according to IEC61400-1 Ed. 3
Classification
Vref [m/s]
50
42.5 37.5
Based on the long-term representative wind speed distributions, Vref, has been determined following the
EWTS II1 guideline and IEC 61400-1 using the statistical Gumbel model.
The reference velocity in 85 m above ground level, is estimated for the wind met mast location height of 85
m as Vref = 28.5 m/s. This is well below the limits of IEC wind class III (37.5 m/s) for both the EWTS II
approach and using the Gumbel method, i.e. the site is seen as a class III site.
Classification according to turbulence
Atmospheric turbulence is the set of seemingly random and continuously changing air motions that are
superimposed on the wind’s average motion. Atmospheric turbulence impacts wind energy in several ways,
specifically through power performance effects, impacts on turbine loads, fatigue and wake effects, and
noise propagation.
The classification parameter is the representative turbulence intensity defined as ambient turbulence
intensity plus 1.28 times the standard deviation of the 2 second wind speed values around the 10 minutes
average.
Assessment of wind speed distribution
The criteria of the wind distribution determines the load groups used for calculating the technical exposure.
It proves how good the site specific wind distribution fits to the used standard. In case of deviations a
recalculation can clarify if the WTG fits to the site. The standard bases the averaged wind distribution on
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Weibull curves with shape factor of k=2.0 (equivalent to Rayleigh Distribution). The distribution at the
Yunus site provides a shape factor of k= 2.6 and therefore deviates from the IEC standard assumptions.
The below figure shows the three classes I (red dotted), II (red dashed) and III (green) the wind speed
distribution curves and vertically the borders of the most relevant wind speed range (0.2*V ref to 0.4*Vref).
The blue Yunus curve does exceed the enveloping curves in the lower wind speed groups (up to approx.1214 m/s). Especially for the Class III (represented by green lines) most of the wind speed groups between the
vertical green lines (range from 7 to 15 m/s), the Yunus wind is above the assumption made for the load
groups.
For the Class I and II on the other hand, the lower wind speed groups are approx. balanced with the higher
wind speed groups where the site wind is significant less frequent than the assumption. Ideally, the site
distribution should fit completely below the enveloping curves.
Classification result
The IEC site compliance conformity check also proves certain other parameters which are briefly described
below:
1. Terrain complexity: low
2. Extreme wind: 28.5 m/s
3. Representative turbulences: < B limits
4. Wind distribution: caution (exceedance all classes)
5. Flow inclination: not critical (-8°< α < 8°)
6. Wind shear: not critical (<0.2)
7. Air density: not critical
8. Seismic hazard2: caution (2.1 m/s²)
9. Temperature range: to be confirmed by Turbine supplier; nominal 0.2h/a the WTG is operation in
“extreme temperature range”
10. Lightning rate3: not critical (1.7 flashes/year/km²)
Summarizing findings, HAWA wind farm site can be basically classified for IEC wind class III B based on the
available wind data.
CONCLUSIONS
For the HAWA site, the fatigue and extreme loads of the 1.7-103 wind turbines with an 80m hub height are
within the IEC TC S based on IEC TC IIIB design loads envelope. The installation and operation of the 1.7-103
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wind turbine is approved based on current calculation methods. This conclusion applies only to the input
data considered in the analysis and is contingent on the accuracy of the data provided by the customer. Any
change to the input data must be reviewed by GE to determine if there is a change in turbine suitability
A.3.1.4 Detailed Specifications of WTG
The Project Company considered two turbine models, namely GE 1.7-103 and Gamesa G114-2.1. Table-3
displays some specifications of the turbines as provided by the manufacturers.
Table 4: Turbines Considered
No. of WTGs
Type of WTG
Nominal Power [kW]
Hub height [m]
Rotor diameter [m]
Wind Farm Capacity [MW]
Cut out wind speed [m/s]
Re cut-in wind speed [m/s]
29
G.E 1.7-103
1700
80
103
49.3
20
18
24
G114-2.1
2100
93
114
50.4
25
23
Power Curves and Thrust Curves of WTGs
Table 5: 1. GE1.7-103, at air density of 1.225 kg/m³
Wind Speed at Hub height [m/s]
Power [kW]
Ct
3
3
0.96
3.5
52
0.9
4
105
0.89
4.5
172
0.9
5
259
0.87
5.5
365
0.83
6
485
0.81
6.5
626
0.8
7
782
0.8
7.5
966
0.8
8
1175
0.8
8.5
1391
0.76
9
1548
0.69
9.5
1661
0.59
10
1703
0.49
10.5
1713
0.41
11
1715
0.35
11.5
1715
0.3
12
1715
0.26
12.5
1715
0.23
13
1715
0.2
13.5
1715
0.18
14
1715
0.16
14.5
1715
0.14
15
1715
0.13
15.5
1715
0.12
16
1715
0.11
16.5
1715
0.1
17
1715
0.09
17.5
1715
0.08
18
1715
0.08
18.5
1715
0.07
19
1715
0.06
19.5
1715
0.06
20
1715
0.06
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Table 6: G114-2.1, at air density of 1.225 kg/m³
Wind Speed at Hub height [m/s] Power [kW]
Ct
3
33
0.892
4
146
0.857
5
342
0.834
6
621
0.829
7
1008
0.828
8
1501
0.795
9
1909
0.65
10
2076
0.469
11
2093
0.338
12
2099
0.253
13
2100
0.196
14
2100
0.157
15
2100
0.128
16
2100
0.106
17
2100
0.089
18
2100
0.077
19
2100
0.067
20
2100
0.077
21
2100
0.067
22
1906
0.059
23
1681
0.05
24
1455
0.04
25
1230
0.032
A.3.1.4 WTG and Energy Yield Estimate
The Project Company considered General Electric (GE) and Gamesa turbine models for the energy yield
assessment. Details of wind turbines are as follows:
General Electric: 29 GE 1.7-103 with hub height (hh) of 80 m;
Gamesa: 24 G114-2.1 with hub height (hh) of 93m;
Micrositing is done using topographic survey received from the Project Company. The same micrositing is
used for the energy yield calculations. However, the micrositing may be subject to changes in the detailed
planning by the EPC contractor.
For the energy yield calculation, surrounding wind farms in a radius of 30km have been considered with
two scenarios:
Scenario 1: Wind farms have been considered, which are already completed or under construction, as well
as those which are expected to be completed by the time the HAWA project is completed (total: 474
WTGs).
Scenario 2: All wind farms from Scenario 1 have been considered plus further projects which are estimated
to be implemented additionally in the future (total: 564 WTGs). Namely, additional wind farms in the
upwind side of HAWA wind farm are included.
From the predicted annual energy production (P50) and from the total uncertainty on the energy level,
annual energy yields are calculated for different exceeding probability levels (P50, P75 and P90). The
probability of Exceedance (PoE) describes the minimum annual energy production which will be reached or
exceeded for the respective probability level.
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Applying a Gauss distribution for the statistical analysis, the calculated annual energy production can be
understood as the mean annual energy yield having the highest rate of probability of all single results (P50).
The calculated total uncertainty is understood as standard deviation of the expected results.
All losses and gross and net yields calculated for different PoE levels are summarized for the two WTG types
and two scenarios in Table-7.
Table 7: Losses and gross and net yields calculated for different PoE levels
Model
GE 1.7-103
1 Year Period
Uncertainty%
P50 [MWh/a]
P75 [MWh/a]
P90 [MWh/a]
1 Year Period
Uncertainty%
P50 [MWh/a]
P75 [MWh/a]
P90 [MWh/a]
Scenario 1
Gamesa G114
GE 1.7-103
Scenario 2
Gamesa G114
13.4%
218,874
199,084
181,273
13.5%
220,898
200,787
182,687
13.7%
212,565
192,965
175,324
13.8%
214,425
194,518
176,602
11.6%
218,874
201,712
186,265
12.0%
220,898
200,787
182,687
11.9%
212,565
195,459
180,064
12.3%
214,425
196,679
180,708
A.3.1.5 Uncertainty Assessment
Wind studies are based upon several estimates, expectations and assumptions. Thus there exist possibilities
that the basis of the model may not turn to reality. Therefore, certain uncertainties are considered. For
wind studies and energy predictions, the uncertainties are difficult to quantify through calculations because
these are functions of many independent factors.
A.3.1.6 Analysis of Certain Loss Rate
Losses are found on the whole energetic transformation chain from the rotor (kinetic energy) to the
substation (electrical energy) and are simple add-ups to the total reduction in the calculated energy yield.
This section describes the individual losses considered in the energy yield figures for the wind farm layouts.
Array losses (wake effects)
After passing a turbine, the speed of the wind flow decreases due to the kinetic energy absorbed by the
rotor and due to an increased turbulence caused by the rotation. Until the speed difference to undisturbed
flow is not equalized, the result is a lower energy yield for downwind located turbines.
The losses due to wake effects (park efficiency) are calculated applying the N.O. Jensen Park Model.
Wake losses are calculated using turbines within the wind farm as well as those of surrounding wind farms.
The wake decay constant based on measurement are considered sector-wise and is used for the whole
wind farm.
Turbine Availability
The technical availability describes the percentage of the year the turbine is ready for operation. It is noted
that some turbine down times have contractually the status “available” (e.g. scheduled turbine
maintenance, grid failures), but no energy can be produced in the respective time period
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Annual availability values for the proposed turbine types are assumed to be 97%, respectively 3%
unavailability and therefore losses for all WTG and both scenarios. However, at later development stage of
the project, these might be changed, depending on finally guaranteed values in the signed contracts with
EPC Contractor and/or O&M operator.
Electrical Losses
Electrical losses occur in the step-up transformers inside the wind turbine, the medium voltage internal
cable systems between turbines and the medium voltage metering point at the substation. Additionally the
facility consumption is considered here. Electrical losses occurred by the high voltage system, incl.
transformer and HV-link to the point of common coupling are not considered.
A total electrical loss of 2.5% are calculated including all losses related to equipment and consumption of
the facility and independent of the layout and the scenario.
Turbine Performance
Losses due to the site specific turbine performance apply to the power curve not producing to its reference.
Other causes of energy losses related to the turbine operation are high wind speed hysteresis (due to re-cut
in at lower wind speeds than cut-out) and high wind inflow angles > 8° (tilt). Hysteresis losses of 0.1% for
the GE layout are calculated, based on the Technical Specification for the cut-out and the re-cut in. For the
GAMESA layout negligible losses are calculated. A total turbine performance loss of 0.6% and 0.5% has
been considered for the GE respectively the Gamesa turbines.
Environmental Losses
The environmental losses are referred to losses due to climatic and ambient conditions such as icing,
extreme temperatures, force majeure events, and blade degradations caused from climate ambient
conditions.
For the calculation of loss due to temperature, long term corrected site data has been used. Time series
extracted along with temperature. Reduced energy is calculated where temperature is above the specific
turbine permissible range.
Energy results are mapped along with the overall loss due to environment has been assessed to be 0.5% on
annual energy yield for GE1.7-103 and G114-2.1. Performance degradation due to blade abrade, WTG aging
and other harming of the performance of wind turbine is considered with 0.5% as average over the whole
lifecycle. Total loss associated to the environment is calculated as 1%.
Curtailments
Curtailments apply to losses due to restricted operational conditions such as wind sector management,
power restrictions, shadow flicker mitigation, noise, animal protection etc. So far no curtailment is
intended. The individual losses are added to the total amount as per Table 8:
Table 8: Summary of Losses
Type of Losses
Value
[%]
Wake Effects
9.1
Availability
3.0
Turbine Performance
0.6
Electrical
2.5
Environmental
1
Curtailment
0.0
Total
15.4%
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A.3.1.7 Uncertainty Analysis
Input data and the applied methodology to calculate the wind conditions at turbine hub height and the
annual energy yield are linked to uncertainties, which are assessed by using the following un-certainty
parameters. The uncertainty assessment of the individual elements of the analysis follows international
standards in the wind industry. To calculate the total uncertainty, all single uncertainties are considered as
stochastically independent and the joint uncertainty of independent (un-correlated) uncertainties is the
root of the squared sum.
Uncertainty Model
Independent factors used to account the total uncertainty. Overall uncertainties are described as below:Wind speed (cup-anemometer)
This uncertainty parameter covers amongst others the abrasion, the technical characteristics and the
calibration procedure of sensors. Anemometers utilized in the measurement campaign based for this wind
energy assessment are commercial proven and state-of-the-art devices. An overall uncertainty related to
Wind speed is calculated as 1.5%.
Mounting
The uncertainty category mounting covers the deviations for the mast setup to the IEC standard as well as
the influences to the measurement from the mast itself, booms and mounting clamps. According to the
available information and site visit, the installation layout and measurement setup are generally in
accordance to the IEC standard. An overall uncertainty associated with mounting is 1.4% is considered for
this category
Data Processing
 Data Integrity
The wind data are received in the logger formatted files. Referring the MEASNET guidelines, Classes and
Characterizations of different Situations of Measurement Data Integrity, class D is applied with uncertainty
of 2.5%.
 Data Analysis
Data analysis covers the uncertainty in the data processing and is applied for parameters such as duration
of the measurement campaign, data coverage, measurement consistency, data processing and
methodology in fitting the actual wind frequency distribution to Weibull distribution. Data used is
consisting of 48 months with high data recovery. An overall uncertainty of 2.0% is considered for the data
analysis.
 Long Term Correlation
Uncertainty of the long-term assessment considers quality, consistency and representativeness of the
reference data as well as the correlation between site and reference data. Additionally uncertainties arising
from the applied methodology are covered. An uncertainty of 2.4% is calculated associated with long term
correlation.
Uncertainty related to Prediction Horizon
The prediction horizon describes the variability of the wind climate; just as the historical wind re-sources,
future wind predictions fluctuate around a long-term mean wind speed. For any period of interest the wind
speed fluctuates in the long-term. The uncertainty in terms of standard deviation of this fluctuation around
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the long-term average wind velocity is calculated using MERRA data. The wind speed related uncertainty is
calculated for long term data as 5.1% for 1 year and as 1.6% for 10 years wind average.
Energy related Uncertainties
The predicted energy yield is based on the results of the wind flow modelling which reconstructs the wind
conditions at hub height. Uncertainties of this modelling as well as uncertainties of the applied power curve
and the determined losses are directly related to the energy level.
Modelling
The wind farm area as well as the region is classified as flat, a moderate uncertainty for the flow model can
be used. This includes uncertainties for roughness, orography, WAsP energy calculation model and wind
shear. The main uncertainty was determined in the atmospheric stability which dominated the wind shear-,
strongly fluctuating over a day-night cycle. As the Gamesa WTG using higher towers, the wind shear
uncertainty rules here the model uncertainty for the Gamesa layout.
An uncertainty of 6.1% and 6.9% is associated with layouts of GE 1.7 and Gamesa G114-2.1 respectively.
Power curve
Usually the uncertainty of the turbine power curve can be derived from the power curve measurement
report; it is linked to the expected annual energy level. For the project the turbine manufacturer provided
calculated power curves for the types GE 1.7-103 and G114-2.1. An uncertainty of 6.6% and 7% has been
assumed for GE 1.7-103 and G114-2.1 respectively.
Uncertainty of loss estimation
Further uncertainties in combination with other losses like availability, turbine performances etc. are
considered. Overall uncertainty associated with the losses elaboration is 3.2% and 3.0% for GE 1.7 and
Gamesa G114-2.1 for scenario 1. For scenario 2 the uncertainties of 4.2% and 4.1% for GE 1.7 and Gamesa
G114-2.1 have been calculated. The increase refers to the stronger influence of the wake model for the
future planned WTG in the vicinity for Scenario 2.
The uncertainties for losses are only considered for the determination of the net production.
Table 9: Uncertainty on Net Production-Overall
Model
1-year period
10-year period
Version 06.0
Scenario 1
GE 1.7-103
Gamesa G114
Scenario 2
GE 1.7-103
Gamesa G114
13.4%
11.6%
13.5%
12.0%
13.7%
11.9%
13.8%
12.3%
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Table 10: Uncertainties - Overview
Annual Energy Production
Total Uncertainty of Measurement and Data
Processing
Future wind variability [years]
1-year wind deviation
10-year wind deviation
Modelling
Power curve
Reference WEC
Total Uncertainty on Gross (free flow) Production
(1-year)
Total Uncertainty on Gross (free flow) Production
(10-year)
Losses (uncertainty of loss estimations)
Total Uncertainty on NET Production (1-year)
Total Uncertainty on NET Production (10-year)
energy related
→
↓ wind speed
related [%]
Scenario 1
GE-1.7
G114-2.1
Scenario 2
GE-1.7
G1142.1
4.6
6.3
5.9
6.3
5.9
5.1
1.6
7.0
2.1
6.1
6.6
0.0
6.6
2.0
6.9
7.0
0.0
7.0
2.1
6.1
6.6
0.0
6.6
2.0
6.9
7.0
0.0
13.0
13.2
13.0
13.2
11.2
11.6
11.2
11.6
3.2
13.4
11.6
3.0
13.5
12.0
4.2
13.7
11.9
4.1
13.8
12.3
A.3.1.8 Design of Civil Works
The Project has an installed capacity of 49.3 MW, using wind turbine generators (WTG), each with a
capacity of 1.7MW and an output voltage of 0.69 kV. A substation consisting of step up transformer and
other BOP equipment will connect the farm to the 132 kV power lines. The power from the turbine will be
stepped up to Medium voltage (MV) through a generator step up transformer which will be housed in a
separate compartment in close proximity to the wind turbine tower. Power from all the WTGs in the plant
will be delivered to the substation, and onwards to the grid via the step up transformers and HV
switchgear, built within the boundaries of the wind power plant. The switchgear gantries will be the point
of metering and connection to the 132 kV power lines.
The civil engineering design mainly includes following structures:
 Foundation of WTG Towers
 Foundation of substation and grid interconnection apparatus, i.e. transformer, switchgear
 Construction of permanent buildings (residence and offices) of O&M staff
The design activity of the civil works shall be carried out as part of the EPC contract during early phase of
construction. However, the geo technical risk shall lie under contractor’s responsibility as per the terms of
the EPC Contract.
A.3.1.9 Design of Electrical Works
The 132 kV substation shall consist of two bus sections of a single bus bar with a coupler and two breaker
bays to connect main transformers with the 132 kV double circuit overhead lines (OHL). The Main
Transformers shall meet the N-1 grid code criteria and thus may be two (02) in number (31.5/40/50 MVA
each). The instrumentation transformers (CTs, VTs and CVTs) for all purposes shall be sized according to
requirement. The 132 kV OHLs from the Wind farm substation to the 132 kV to far end connection points
(whether adjacent grid stations or neighboring project substations) are out of the scope of the contractor
and shall be installed and connected by NTDC. The HV/MV switchgear, main power transformer and other
protection equipment shall be of reputable manufacturers, confirming to the requirements to be spelled in
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detail in the EPC Contract and in the EPA. Further, the detailed electrical design will be subject to approval
of both Hawa Energy and NTDC as per the requirements of EPC Contract and EPA.
A.3.1.10 Construction Management
Like all wind power projects in Pakistan, the structure of EPC contract is on a “turnkey” basis. Everything
shall be managed from one platform (one window) of the EPC contractor. The partners of EPC contractor
shall be underneath that platform through “subcontracting” or “joint and several arrangements”. In this
way, the role of Hawa Energy (Pvt) Ltd shall become to supervise and monitor everything.
Hawa Energy (Pvt) Ltd personnel will supervise construction activities right from the beginning. The Hawa
Energy (Pvt) Ltd team will monitor the construction schedule, owner’s engineers and the EPC contractor to
complete the project within given time frame and in-line with HSE guidelines.
Hawa Energy (Pvt) Ltd requires careful management for construction. To achieve this, Hawa Energy (Pvt)
Ltd will prepare a Construction Management Master Plan taking into account all relevant aspects. The
master plan shall be regularly reviewed, updated and shared with all project stakeholders.
Construction Management Plan depends on the nature of work, likelihood of disruptions, impact on local
amenity, dangers or risks involved and any other relevant issue required to be addressed under the
planning permit. In order to manage all the above operations correctly, Hawa Energy (Pvt) Ltd shall have a
consultant as a “Construction Supervisor” who shall supervise the quality and progress of all contractors
and give approvals of the milestones.
A.3.1.11 O & M Management
The O&M shall be managed by the EPC Contractor for the initial 2 years of Warranty Period. It will be
followed by 8 years O&M Contract to be managed by O&M Operator for a long term O&M Agreement,
which has been signed directly with the WTG manufacturers, valid till the 10th anniversary of commercial
operations. The local team shall remain part of the O&M and shall gradually take over after having On Job
Trainings (OJT). O&M management will be established with the principle of requiring “few on-duty staff”.
After entering the electrical equipment and machinery to their stable operation mode, the wind turbine
and associated apparatus shall be managed with “no on-call staff and few on-guard staff”.
The production area includes facilities such as generators, transformers, and the substation. There shall be
buildings for protection and control, telecommunication, DC power supply and for administrative purposes.
A.3.1.12 Financial Feasibility
The desired tariff is US ¢ 10.4482 per kWh levelized over 20 years. The Project Cost is US$ 127,047,859
including US$ 97,600,355 for the EPC. The Debt to Equity Ratio is 75:25. The loan is 100% foreign loan at
LIBOR 3- months. The loan repayment term is 10.5 years after COD with 18 months of grace period
No.
1
2
3
4
5
6
7
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Table 11: Capital Cost
Cost Head
EPC Cost
Duties and Taxes
Total EPC Cost
Non-EPC Cost
Project Development Cost
Pre-COD Insurance
Financial Charges
Interest during Construction
Value in US $
95,000,000
2,600,355
97,600,355
1,083,625
9,834,956
1,282,500
3,784,608
3,824,159
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8
9
Debt Service and Other Reserves
Working Capital and Contingencies
Total Project Cost
6,368,906
3,268,750
127,047,859
Table 12: O&M Cost
Cost Head
Company O&M Expenses (incl.
corporate cost) p.a.
Insurance during O&M
Sub Total
Year 01-02
3,100,000
Year 03-05
2,810,000
Year 06-10
3,000,000
All values in US $
Year 11-20
3,130,000
1,120,000
4,220,000
1,120,000
3,930,000
1,120,000
4,120,000
1,120,000
3,230,000
Table 13: Debt Servicing
Description
No.
1
2
3
4
5
6
7
8
9
Value
Total Project Value
Total value of Debt @ 75% of total Project Value
LIBOR 3-month
Spread
Debt Mark Up
Loan Tenure
Repayment Period
Grace Period
Re-Payment Schedule (Principal and Mark Up)
127.05Mn
95.3Mn
0.5%
4%
Variable
11.5 years
10 years from CoD
18 months
Not Yet Finalized
A.4. Parties and project participants
Party involved
(host) indicates host Party
Private and/or public entity(ies)
project participants
(as applicable)
Indicate if the Party involved
wishes to be considered as project
participant (Yes/No)
Islamic
(host)
Republic
of
Pakistan Renewable Stars (Pvt.) Ltd
Yes
Islamic
(host)
Republic
of
Pakistan HAWA Energy (Pvt) Ltd
No
A.5. Public funding of project activity
There is no public funding involved in the project activity.
SECTION B.
Application of selected approved baseline and monitoring methodology and
standardized baseline
B.1.
Reference of methodology and standardized baseline
The approved consolidated baseline and monitoring methodology ACM0002 (version 16) “Retrofit,
rehabilitation (or refurbishment), replacement or capacity addition of an existing power plant or
construction and operation of a new power plant/unit that uses renewable energy sources and supplies
electricity to the grid”
B.2.
Applicability of methodology and standardized baseline
The proposed project activity meets the applicability criteria listed in the approved consolidated baseline
and monitoring methodology ACM0002 version 16 as show below:
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Applicability criteria
This methodology is applicable to grid-connected
renewable power generation project activities that:
(a) install a new power plant at a site where no
renewable power plant was operated prior to the
implementation of the project activity (greenfield
plant); (b) involve a capacity addition; (c) involve a
retrofit of (an) existing plant(s); or (d) involve a
replacement of (an) existing plant(s).
The project activity is the installation, capacity
addition, retrofit or replacement of a power
plant/unit of one of the following types: hydro power
plant/unit (either with a run-of-river reservoir or an
accumulation reservoir), wind power plant/unit,
geothermal power plant/unit, solar power plant/unit,
wave power plant/unit or tidal power plant/unit.
In the case of capacity additions, retrofits or
replacements (except for capacity addition projects
for which the electricity generation of the existing
power plant(s) or unit(s) is not affected): the existing
plant started commercial operation prior to the start
of a minimum historical reference period of five
years, used for the calculation of baseline emissions
and defined in the baseline emission section, and no
capacity addition or retrofit of the plant has been
undertaken between the start of this minimum
historical reference period and the implementation of
the project activity;
In case of hydro power plants at least one of the
following conditions must apply:
 The project activity is implemented in an existing
single or multiple reservoirs, with no change in
the volume of any of the reservoirs; or
 The project activity is implemented in an existing
single or multiple reservoirs, where the volume
of any of reservoirs is increased and the power
density of each reservoir, as per definitions given
in the Project Emissions section, is greater than 4
W/m2 after the implementation of the project
activity; or
 The project activity results in new single or
multiple reservoirs and the power density of each
reservoir, as per definitions given in the Project
Emissions section, is greater than 4 W/m2 after
the implementation of the project activity.
In case of hydro power plants using multiple
reservoirs where the power density of any of the
reservoirs is lower than 4 W/m2 after the
implementation of the project activity all of the
following conditions must apply:
 The power density calculated for the entire
project activity using equation 5 is greater than 4
W/m2;
 All reservoirs and hydro power plants are located
at the same river and were designed together to
function as an integrated project that collectively
constitutes the generation capacity of the
combined power plant;
 The water flow between the multiple reservoirs is
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Comments
The proposed project activity meets the applicability
criteria (a). It is a grid-connected wind power
generation project activity that will install a new
power plant at a site where no renewable power
plant was operated prior to the implementation of
the project activity (greenfield plant)
The project activity is the installation of a wind power
plant. Therefore it meets this applicability criterion.
n/a. The project activity is a greenfield activity.
n/a. The project activity is not a hydro power plant.
n/a. The project activity is not a hydro power plant.
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not used by any other hydropower unit which is
not a part of the project activity;
 The total installed capacity of the power units,
which are driven using water from the reservoirs
with a power density lower than 4 W/m2, is lower
than 15MW;
 The total installed capacity of the power units,
which are driven using water from reservoirs
with a power density lower than 4 W/m2, is less
than 10% of the total installed capacity of the
project activity from multiple reservoirs.
The methodology is not applicable to the following:
 Project activities that involve switching from
fossil fuels to renewable energy sources at the
site of the project activity, since in this case the
baseline may be the continued use of fossil fuels
at the site
 Biomass fired power plants
 A hydro power plant that results in the creation
of a new single reservoir or in the increase in an
existing single reservoir where the power density
of the reservoir is less than 4 W/m2.
In the case of retrofits, replacements, or capacity
additions, this methodology is only applicable if the
most plausible baseline scenario, as a result of the
identification of baseline scenario, is the continuation
of the current situation, i.e. to use the power
generation equipment that was already in use prior to
the implementation of the project activity and
undertaking business as usual maintenance.
n/a. The project activity is a grid-connected wind
power generation project.
n/a. The project activity is a greenfield plant
In addition, the project meets the applicability criteria of the Tool to calculate the emission factor for an
electricity system (05.0.0) as follows:
I. THIS TOOL MAY BE APPLIED TO ESTIMATE THE OM,II. This tool is applicable since the proposed project
III.
BM AND/OR CM WHEN CALCULATING BASELINE
EMISSIONS FOR A PROJECT ACTIVITY THAT
SUBSTITUTES GRID ELECTRICITY, I.E. WHERE A
PROJECT ACTIVITY SUPPLIES ELECTRICITY TO A GRID
OR A PROJECT ACTIVITY THAT RESULTS IN SAVINGS OF
ELECTRICITY THAT WOULD HAVE BEEN PROVIDED BY
THE GRID (E.G. DEMAND SIDE ENERGY EFFICIENCY
PROJECTS).
THE TOOL IS NOT APPLICABLE IF THE PROJECT
IV.
ELECTRICITY SYSTEM IS LOCATED PARTIALLY OR
TOTALLY IN AN ANNEX-I COUNTRY.
Version 06.0
activity involves the generation of electricity from wind
energy and its supply to the Pakistan national grid
system.
The project electricity system is the Pakistan nationalgrid-system. Pakistan is not an Annex I country.
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B.3. Project boundary
Source
Project scenario
Baseline scenario
Source 1
GHGs
Included?
Justification/Explanation
CO2
Yes
Main emission source as per ACM0002 version 13.3.0
No
No
Minor emission source as per ACM0002 version 13.3.0
Minor emission source as perACM0002 version 13.3.0
…
CH4
N2O
…
CO2
CH4
N2O
…
…
Source 1
…
…
CO2
No
CH4
No
N2O
No
Source 2
Zero emissions since this a renewable energy project (wind
energy)
Zero emissions since this a renewable energy project (wind
energy)
Zero emissions since this a renewable energy project (wind
energy)
…
Source 2
…
CO2
CH4
N2O
…
…
…
…
B.4.
Establishment and description of baseline scenario
The project activity involves the installation of a new grid-connected renewable power plant. Therefore,
the baseline scenario is:
“Electricity delivered to the grid by the project activity would have otherwise been generated by
the operation of grid-connected power plants and by the addition of new generation sources, as
reflected in the combined margin (CM) calculations described in the Tool to calculate the
emission factor for an electricity system''(version 05.0.0).
Therefore the baseline can be described as follows:
B.4.1
Overview of Pakistan’s Power Sector
The Ministry of Water and Power acts as the executive arm of the GOP in execution of Federal Government
policies and strategy in the power sector. It also coordinates with relevant provincial governments and their
agencies in achieving national policy objectives.
The National Electric Power Regulatory Authority (NEPRA) set up under the Regulation of Generation,
Transmission and Distribution of Electric Power Act, 1997 (known as the “NEPRA Act”) is the apex
regulatory body, which is mandated to act as an independent regulator for the provision of electric power
services in Pakistan. The Karachi Electric Supply Corporation (KESC) now names as K-Power and National
Transmission and Dispatch Company (NTDC) are the two companies responsible for transmission of
electricity; KESC is a private sector company awarded license by the NEPRA as transmission system
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operator within the Karachi metropolitan city, whereas, NTDC is the license holder as the transmission
system operator, also licensed by NEPRA transmits power purchased through the Pakistan Power Holding
Company Ltd. / Central Power Procurement Agency (CPPA), from GoP owned five thermal generation
companies (GENCOs) and independent power producers (IPPs). NTDC is also the System Operator for the
secure, safe and reliable operation, control and dispatch of generation facilities as well as the Transmission
Network Operator for the operation and maintenance, planning, design and expansion of the national
transmission network. National Power Control Centre (NPCC) is the central dispatch from where the nine
public sector and KESC in private sector are awarded license to distribute electricity all over Pakistan.
Besides, NEPRA also has awarded two distribution licenses to private sector companies to distribute
electricity within the housing colonies.
WAPDA holds charge of the hydel generation in public sector, development and management of water in
its reservoirs and related infrastructure. Pakistan Atomic Energy Commission (PAEC) is the designated
agency for the generation of nuclear power in the country. Private sector companies established to execute
conventional and non-conventional power projects as Independent Power Producers (IPPs). More than 30
IPPs are currently operating in the country running commercial power projects based on thermal (FO, HSD,
Gas), Large and Small Hydel and alternative and renewable energy projects in the country. The country is
also importing electricity from abroad. In this regard, Pakistan has signed electricity import agreement with
Iran. Option has also been considered for import of electricity from India.
Private Power and Infrastructure Board (PPIB), is established as a “one window” facilitator for conventional
private power sector generation projects, including hydel projects of above 50 MW capacity. Whereas,
Alternative Energy Development Board (AEDB) is a “one window” facilitator of the GoP for alternative and
renewable energy projects including small hydel projects up to 50 MW capacity. Both AEDB and PPIB work
very closely to ensure consistency of policy outlook and implementation; however, each organization has
distinct role and responsibilities.
The Provincial Governments of Baluchistan, Khyber-Pakhtunkhwa, Punjab and Sindh support the
development and implementation of power projects within their territories. Similarly, the Northern Areas
comprising the Gilgit-Baltistan (GB) region and the State of Azad Jammu and Kashmir (AJK) support
development of power projects through local departments. An organogram of the Pakistan power sector
highlighting the inter-relation of various agencies is given in Figure 8.
Figure 8: Institutional Framework of Power Sector in Pakistan (Source: M/o W&P)
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The electricity sector of Pakistan is facing acute shortages in supply which have led to power outages on a
large scale. The wide fluctuation of international oil prices, higher cost due to gradual phasing out of
subsidies, and the circular debt problem have also exacerbated the situation of power supply in the
country.
The Government of Pakistan is taking diverse measures to circumvent the problem of capacity shortage.
These include expansion and refurbishment of existing plants, induction of new power plants - mainly in
the private sector, encouragement of renewable energy, development of rental power plants, and
acquisition of power from captive power plants. This section presents the demand-supply balance till the
year 2030 taking into account the generation expansion plan and the load forecast developed by NTDC.
B.4.2
Installed Generation Capacity
Pakistan faces chronic electricity shortages due to demand growth, no addition in generation capacity, high
system losses, and seasonal reductions in the availability of hydropower, circular debt. Etc. rotating power
outages (“load shedding”) are common and many villages are not yet electrified.
The power sector in Pakistan is a mixed industry of thermal, hydro and nuclear power plants. Originally, the
ratio of hydel to thermal installed generation capacity, in the country was about 67% to 33% (1985) but
with the passage of time, due to different reasons more of thermal generation was added and thereby
reduced share of hydel generation. At present, this hydel to thermal installed generation capacity ratio
turns to about 29% to 67%4. As on June 30, 20145 The Installed capacity of Pakistan as on 30th June, 2014
was 23,636 MW; of which 15,887 MW (67.22%) was thermal, 6893 MW (29.19%) was hydroelectric, 750
MW (3.17%) was nuclear and 105.9 MW was wind. It is a drawback of the country that is power production
dominated by thermal power plants running on oil and gas. Pakistan is a country which is heavily
dependent on import of oil for its domestic energy requirement due to large amount of oil-fired power
plants.
The country meets its energy requirement around 41% by indigenous gas, 19% by oil, and 37% by
hydroelectricity. Coal and nuclear contribution to energy supply is limited to 0.16% and 2.84% respectively
with a vast potential for growth.
TYPE
Hydel - WAPDA
Thermal – WAPDA
Thermal IPPs
Thermal KESE
Nuclear (PAEC)
Wind
Total
Table 14: Installed electricity Capacity
MW
%
6893
29.16%
4900
20.73%
8771
37.11%
2216
9.38%
750
3.17%
105.9
0.45%
23,636
100.00%
4Pakistan
Energy Yearbook 2014 (As PYE 2015 have not been published yet)
5Pakistan
Energy Yearbook 2014 (As PYE 2015 have not been published yet)
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29.16%
20.73%
100.00%
37.11%
9.38%
0.45%
3.17%
Hydel - WAPDA
Thermal – WAPDA
Thermal IPPs
Nuclear (PAEC)
Wind
Total
Thermal KESE
Figure 9: Sector Wise Installed Generation Capacity of Pakistan
B.4.3
Electricity Generation by Sector and Source
During the fiscal year 2013-14, the total electricity generation in the country was 103,670GWh6 of which
the share of thermal electricity generation was 66,707GWh (64.35%), hydel power plants were 31,873GWh
(30.74%). The increasing share of thermal electricity generation increased the utilities financial burden
particularly in foreign exchange. It is a strong need of the time to increase the hydel generation by adding
new hydropower plants. The share of private sector is increasing as compared to the public sector.
Electricity generation by source and sector during fiscal years 2008-09 to 2013-14 are shown in the
following table:
Table 15: 1. : Energy Generation by Sector and Source (GWh)
Sector / Source of
2008-09 2009-10 2010-11 2011-12 2012-13 2013-14
Generation
6Pakistan
Public Sector
48,642
50,189
47,833
45,972
46,742
49,212
Public (Hydel)
27636
27,927
31,685
28,207
29,326
31,656
Public (Thermal)
19,520
19,594
13,018
12,893
13,235
13,055
Public (Nuclear)
1,486
2,668
3,130
4,872
4,181
4,501
Private Sector
46,005
49,577
52,749
52,850
52,152
56,102
Private (Hydel)
547
565
305
445
706
1015
Private (Thermal)
45,458
49,012
52,444
52,405
51,446
55,087
Total
94,647
99,766
100,582
98,822
98,894
105,314
Energy Yearbook 2014 (As PYE 2015 have not been published yet)
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B.4.3.1 Thermal Generation
Majority of Pakistan’s power generation is thermal, with furnace oil, high-speed diesel and natural gas as
fuels, coal is almost non-existent. During 2013-14, the share of thermal power generation in the energy mix
of Pakistan was 64.4%7 as against 64.99%8during last year.
Thermal Power Generation and Fuel Consumption
Gas: During the year 2013-14, the share of electricity generated using gas in the total electricity generation
of the country was 39.31% while this share during 2012-13 was 44.02%9
Oil: During the year 2013-14, the share of electricity generated using oil in the total electricity generation of
the country was 60.52% while this share during 2012-13 was 55.91%11
Coal: During the year 2013-14, the share of electricity generated using coal in the total electricity
generation of the country was 0.16% while this share during 2012-13 was 0.06%11
B.4.3.2 Hydel Generation
Pakistan has a potential of around 60,000 MW hydropower, whereas the installed hydel power capacity of
Pakistan at the end of the fiscal year 2014 was 6,893MW10. The share of existing hydel power installed
capacity to the total installed generation capacity of the country is only 29.29% while this share in year
1985 was around 67%. The share of hydel power generation during fiscal year 2013-14, in the energy mix of
Pakistan was 30.7% as against 31.06% during same period last year. Most of the installed hydel power
capacity of the country is owned by public sector (WAPDA) and only 84 MW10 installed hydel power
capacity is in private sector.
B.4.3.3 Nuclear Power Plants
Pakistan Atomic Energy Commission, interalia, undertakes the projects of nuclear power plants’
development, operation and maintenance in the country. The 1st Nuclear Power Plant (NPP) of the
country, namely Karachi Nuclear Power Plant (KNAUPP), was commissioned in 1971 in Karachi through a
turn-key agreement. The total installed capacity of this plant was 137 MW and the useful life of this plant
was 30 years. However, after completion of 30 years life, Pakistan Nuclear Regulatory Authority extended
the operational life of this plant by another 15 years at reduced capacity. The 2nd NPP of the country,
namely, the Chashma Nuclear Power Plant (CHASNUPP-I) was commissioned in year 2000 also through a
turnkey agreement by China National Nuclear Corporation. The 3rd NPP namely Chashma Nuclear Power
Plant (CHASHNU-II) was commissioned on May 18, 2011. The installed capacity of this plant is 325 MW.
Total installed capacity of NPPs, as on June 30, 2014, in the country was 750 MW 10 above as against the
total installed electricity generation capacity of 23,636 MW, which constitutes a share of NPP to the total
installed generation capacity as 3.17%. The share of electricity generated through NPPs in the country
during 2013-14 was recorded as 5090GWh (4.9%) as against 4,553 GWh (4.74%) in the preceding year.
B.4.3.4 Renewable Energy
7Pakistan
Energy Yearbook 2014 (As PYE 2015 have not been published yet)
8Pakistan
Energy Yearbook 2013
9State
of Industry report 2014
10Pakistan
Energy Yearbook 2014 (As PYE 2015 have not been published yet)
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Pakistan like other developing countries of the region, is facing a serious challenge of energy deficit. Hence,
Pakistan is working to expand the use of renewable energy to help bridge the gap of energy deficiency in
the country. The country is blessed with natural resources that can be utilized to generate electricity.
Renewable resources that are technologically viable and have prospects to be exploited commercially in
Pakistan include wind energy, solar energy, micro-hydel, bio-energy, and emerging technologies like Fuel
cell. Pakistan can benefit from these resources and can supplement existing energy resources as well as can
use as primary energy sources when no other option is available.
The coastal belt of Pakistan is blessed with a wind corridor that is 60 km wide (Gharo-Kati Bandar) and 180
km long (up to Hyderabad). This corridor has the exploitable potential of 50,000 MW of electricity
generation through wind energy. In addition to that there are other wind sites available in coastal areas of
Baluchistan and some in Northern Area. Technically the grid can take upto 30-40% of wind energy. Most of
the remote villages in the south can be electrified through micro wind turbines. More than 5000 villages
can be electrified through wind energy in Sindh, Baluchistan and Northern Areas.
The Government of Pakistan established the Alternative Energy Development in 2003 to create an
environment in the country that is conducive for investment from the private sector in renewable energy.
The Government of Pakistan is putting greater emphasis on renewable energy and has set a target of 10%
share of renewable energy or 2700 MW in the country’s energy mix by 2015.
Besides, AEDB the Irrigation and Power Department of Punjab and Khyber Pakhtunkhwa are actively
involved in development of small hydel power projects. The provincial/AJK organizations which are involved
in development of small hydropower projects are as under:
Pakhtunkhwa Hydel Development Organization (PHYDO)
Punjab Power Development Board (PPDB)
Irrigation and Power Development Board, Sindh
AJK Hydro Electric Board (AJKHEB) and AJK Private Power Cell
Northern Area Public Works Department
At present, the share of wind energy in the national grid of the country is non-existent as against a wind
power potential of 50,000 MW in the country.
B.4.4
Pakistan Power Demand Analysis
The statistics show that the national grid electricity is available for the 70% of the population. At present,
24.711 million consumers in different sectors of economy are connected to the Power sector of Pakistan.
Domestic sector is the largest consumer of the electricity followed by the industrial, agricultural,
commercial and others. The details regarding sector-wise number of consumers connected to national grid
and consumption of electricity during the financial year 2013-14 (PEPCO & KEL) are given in Table 16.
11State
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Table 16: Sector-wise Electricity Consumers in Pakistan and Electricity Consumption in 2013-1411
Consumers Category
No. of Consumers (As on 30th Jun 2014)
Nos.
Consumption (Jul 2013 -Jun 2014)
% age
GWh
% age
Domestic
20,972,698
84.91%
35,404
46.63%
Commercial
3,073,239
12.44%
5,941
7.82%
Industrial
325,752
1.32%
22086
29.09%
Agricultural
312,988
1.27%
7699
10.14%
Public Lighting
9,232
0.04%
498
0.66%
Others
5291
0.02%
4297
5.66%
Total
24,699,200
100%
75,925
100%
Figure 10: Electricity Consumers by Type
Figure 11: Sector Wise Electricity Consumption
B.4.5
Revenue Collection from Sale of Electricity
The determination of tariff for electric power services is one of the primary responsibilities of NEPRA.
NEPRA determines electricity tariff, keeping in view the principles of economic efficiency and service quality
according to the prescribed Tariff Standards and Procedure Rules, 1998. Under Section 7(3) of the NEPRA
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Act, NEPRA has expressly conferred the power to determine tariff rates, charges and other terms and
conditions for supply of electric power services by generation, transmission and distribution companies and
to recommend those to the Federal Government for notification.
As stated above, the electricity mix of the country is pre-dominated by the thermal power generation. The
electricity generated through the thermal power plants impacts the overall basket tariff rate of electricity.
The figure below indicates the energy mix of the country and gives out the impact of the thermal electricity
on overall basket tariff rates. It can be seen from the figure that the share of electricity generated during
2013-14 has a share of 64.4%12, however the share of thermal power generation in overall basket tariff rate
is 89.4%.
All the generated electricity is supplied to national grid, from where it is wheeled to the local power
distribution companies. The distribution companies sell the electricity to end consumers and collect the
revenue on the sol energy based on rates determined by NEPRA. The revenue collected from sale of
electricity is used to pay for the operational charges of the grid operators and the electricity generators.
The data for the last seven years regarding revenue collection and recovery percentage from the end
consumers indicates that the average revenue collection has been within the range of 90%. The difference
of payments is due to reasons including delays in NEPRA’s application of the Fuel Price Adjustment
mechanism and lesser collection from public and private sector consumers. This requires the government
to subsidies the electricity sector.
B.4.6
Existing Grid Infrastructure
In Pakistan, there are two companies which are presently engaged in the business of electric power
transmission. One is National Transmission and Dispatch Company Limited and the other is Karachi Electric
Supply Company Limited. NTDC is the National Grid Company of Pakistan and is exclusively responsible for
electric power transmission in whole country except for the area served by KESC. NTDC is a public sector
company and came into existence as a result of restructuring of WAPDA in 1998 and then has succeeded in
obtaining a transmission license by NEPRA in 2002. NTDC is responsible for overall reliability, planning and
coordination of the electricity in Pakistan except the area under KESC. At present, NTDC owns a network of
500 kV, 200 kV and some 132 kV (links) transmission lines and grid stations in its network.
Besides NTDC, the other company which is engaged in electricity power transmission business of Pakistan is
Karachi Electric Supply Company Limited. K-Electric is a vertically integrated company operating in private
sector. Earlier the company was in public sector and responsible for generation, transmission and
distribution of electric power in its area. Later-on, K-Electric was privatized as a single vertically integrated
electric power utility. KE at present has three separate licenses; one for their generation business, second
for the distribution of electricity in its designated area and third is for their transmission network. The
transmission network of KESC is connected to the national grid of the country by 220 kV and 132 kV links.
12Pakistan
Energy Yearbook 2014 (As PYE 2015 have not been published yet)
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Figure 12: Existing NTDC Network of Pakistan (Source: NTDC)
The integrated transmission system of NTDC comprises of 500 kV and 220 kV transmission lines and grid
stations.
B.4.7
Power source planning and grid planning
Government of Pakistan is anxiously working to cope with the current energy crises. It is intending to
explore every possible energy resource to enhance overall energy supplies enabling it to meet increasing
energy needs. While exploiting different options the focus of the GoP to meet the increasing energy is:
•
Adequate Energy Supplies: The energy sector plans focus on development of indigenous energy
resources, import of energy at competitive prices to meet the deficits, infrastructure for delivery of
energy to the consuming sectors, and systems to assure reliability, efficiency, and economy of
supply.
 Security of Energy Supply: Recognizing the uncertainty in the international energy markets and
emerging requirements of other developing economies such as India and China, the energy plans
focus on maximum utilization of indigenous energy resources to lower the dependence on
imported energy, and diversification of the energy mix to manage risks and external shocks.
• Long-term Viability of the Energy Sector: The cornerstone of the government policy to assure long
term sustainability of the energy sector is shifting from a predominantly state controlled industry to
a structure where the government maintains a strategic presence, while the private sector plays a
leading role in development of the energy sector. Supporting policies to achieve this objective
include appropriate distribution of responsibilities within the government institutions for policy
formulation, regulation, administration to avoid overlaps and conflicts, policies and regulations that
provide appropriate incentives and encourage competition in the private sector, and sustainable
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pricing regimes that account for cost-of-service and subsidies that are transparent and address the
social and environmental concerns.
B.4.7.1 Demand Forecast
Evaluation of Supply-Demand Balance
NEPRA in its State of Industry Report 2014 has given an overview of the surplus/deficit in demand and
supplying during NTDC’s peak hours. The data stated therein gives actual figures up to 2014 and then
projected figures for the year 2015 to 2020. Similar data is tabulated for KESC grid network. The
demand/supply deficit data is revealed in Table 17 below:
Table 17: Surplus/Deficit in Demand and Supply during NTDC's System Peak Hours
A: Actual Figures
Financial Year ending 30th
Generation
Demand During NTDC's
Surplus / Deficit (MW)
June
Capability
System Peak Hours (MW)
2010
12751
18467
-5716
2011
13193
18521
-5328
2012
12320
18940
-6620
2013
14600
18827
-4227
2014
16170
20576
-4406
B: Project Figures
Planned Generation
NTDC Project
NTDC's Projected
Surplus /
Financial Year ending
Capability as per NTDC
Demand Growth
Demand During
(Deficit)
30th June
(MW)
Rate (%)
Peak Hours (MW)
(MW)
2015
18499
1.98
23242
-4743
2016
18791
4.66
23711
-4920
2017
20304
4.73
24871
-4567
2018
23734
4.75
26105
-2371
2019
26480
4.74
27408
-928
2020
29895
---28773
1122
Surplus/Deficit in Demand and Supply during KESC's System Peak Hours
Financial Year ending 30th
Generation
Demand During KESC's
Surplus / Deficit (MW)
June
Capability
System Peak Hours (MW)
2010
2393
2562
-169
2011
2237
2565
-328
2012
2163
2596
-433
2013
2246
2778
-532
2014
1951
2929
-978
C: Project Figures
Planned Generation
KESC Project
KESC's Projected
Surplus /
Financial Year ending
Capability as per KESC
Demand Growth
Demand During
(Deficit)
30th June
(MW)
Rate (%)
Peak Hours (MW)
(MW)
2015
1825
5
3075
-1250
2016
2097
5
3229
-1132
B.4.7.2 Options to meet future Energy Needs
With the progress and development in public and private sectors in the country and improvement of living
standards of general public, energy demand has significantly increased. Present energy scenario manifest
that existing energy generation capacity of installed projects is not able to meet the increasing energy
demand. The challenge before Pakistan is to continually expand its power generation and distribution
infrastructure by augmenting limited public resources with substantial private sector participation and
foreign direct investments, while at the same time devising a sustainable long-term growth strategy that
optimizes the use of inexpensive energy choices with minimal financial and economic impacts. In this
respect, technologies that are commercially competitive, such as gas-fired combined-cycle plants, coal
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power plants, large and small hydel plants, alternative and renewable energy power plants (including wind
and solar), assume increasingly important roles.
The nations have been striding to harness and utilize indigenous resources of energy which can help
ensuring self-reliance, energy security and environment safety and within limited financial impact that
would not go beyond the purchaser limit.
GoP on these lines have been planning to diversity the energy mix and developing integrating planning for
ensuring energy supplies. The GoP prepared a Power Generation Plant 2005-30 in the Medium Term
Development Framework (MTDF 2005-10). The projections made at that time are given in Figure 13 below:
Figure 13: Indigenous Supply Projections
While going through different options, the indigenous energy supply of the GoP has been a focus. While
designing the policies and strategies, the GoP has envisioned that indigenous energy supplies have to play a
key role. Among the indigenous energy supply options, hydel, coal and AREs are regarded as most
important indigenous energy source. Presently the supply of natural gas, hydel and nuclear are sourced
locally. While a relatively small proportion of crude oil, petroleum products and coal is produced locally as
against imports. ARE and coal supplies have a very small contribution in the country’s total energy mix.
To achieve these objectives, the government has adopted an approach based on implementation of
integrated energy development plans that take into account cross-sectoral economic impacts of energy
options and projects through the supply and demand chain. Policies and plans in place target further
development of indigenous conventional energy resources including oil and gas, hydel (hydroelectric), coal
and renewables by providing appropriate incentives and a level playing field to the private sector.
B.4.8
Potential of Indigenous Electricity Resources in Pakistan
B.4.8.1 Hydropower Potential in Pakistan:
The total hydro-power resource in the country has been estimated at over 60,000 MW. Most of the
resources lie in the North of the country, which offers sites for large scale (100 MW to 7,000 MW) power
projects. Smaller (less than 50 MW) sites are available throughout the country. Figure 14 and the Table-18
below gives province wise distribution of hydropower potential in the country.
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Figure 14: Hydropower Potential in Pakistan (Source: PPIB/AEDB)
Table 18: Hydropower Potential in Pakistan
Sr.
No.
Province
Projects
Above 50 MW
Hydel Potential
Below 50 MW
Total
(MW)
1
Gilgit Baltistan
19,890
1300
21,190
2
Khyber Pakhtunkhwa
24,281
750
25,031
3
AJ&K
6,002
337
6,339
4
Punjab
6,770
560
7,330
5
Sindh
-
191
191
56,943
3,138
60,081
TOTAL:
B.4.8.2 Coal Power Potential in Pakistan:
Due to the present energy crises in the world and particularly in Pakistan, the government and power
generation sectors have shown keen interest in the indigenous coal resources for its utilization in the
electric power generation, cement and other related industries. The development of coal will have an
important multiplier effect by creating a number of supporting industries which will provide additional
employment for skilled labour, income for the mining community and experience with new and modern
technologies. Production of domestic coal will reduce the demand for imported fuels which drains an
inordinate percentage of Pakistan’s scarce foreign exchange resources.
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Figure 15: Coal Reserves of Pakistan (Source: Govt. of Sindh)
Coal from different areas of Pakistan generally ranges from lignite to high volatile bituminous. These coals
are friable with relatively high content of ash and sulphur. Coal of Pakistan is being used for cement, sugar,
steel, brick-kiln, domestic supply and by other industries including, Water and Power Development
Authority. Pakistan is ranked 7th internationally in having lignitic coal reserves.
Most of the world’s lignite coal is found in Asia and Pakistan is tops lignitic coal-bearing countries in Asia.
97% of coal reserves of Pakistan belong to lignite and remaining only 3% are sub-bituminous to bituminous.
So far, out of an estimated 475bt of sub-bituminous and lignite reserves of the world, 46.7% occur in Asia,
34.9% in Europe, 9.6% in America and 7.7% in Australia. The recoverable reserves of lignite in Asia are as
follows: Pakistan, 36.9%; Indonesia, 31.6%; China, 27.4%; India, 2.8% and Thailand, 1.2%. The percentage of
lignite to hard coal in Asia is represented as follows: Pakistan, 97%; Thailand, 83%; Indonesia, 58% and
India, 3% (Ghaznavi, 2002). The percentage of hard coal to overall reserves in Asia is as follows: Pakistan,
3%; Thailand, 17%; Indonesia, 42% and India, 97% Working coal mines in Balochistan are Mach, Sor RangeDeghari, Narwar-Pir Ismail Ziarat, Sharigh, Sinjidi, Khost-Shahrag-HarnaiDuki, Chamalang-Bahlol and Kingri
coalfields whereas a non-developed coalfield is situated in Toi Nala (GhozeGhar) with total reserves of
about 217mt; working coal mines in Punjab are Makerwal and Salt Range coalfields with total reserves of
about 235mt; working coal mines in Sindh are Lakhra and Meting-Jhimpir coalfields whilst non-developed
coalfields are Sonda-Thatta, Jherruck, Ongar, Indus East, Badin and Thar coalfields with total reserves of
about 185,456mt; working coal mines in KPK are Hangu/Orakzai, Cheratand Gulakhel coalfields and those
of non-developed coal fields in the same region is the Shirani coalfield with total reserves of about 90mt
and, lastly, working coal mines in Azad Kashmir are Kotli coalfields with total reserves of about 9mt. With
this, the grand total reserves of Pakistan are about 186,007mt. A few coalfields in Balochistan and most
coalfields in Sindh are non-developed. Due to the prevalent energy crises, it is necessary to find new
coalfields, utilize explored coalfields and introduce semi-mechanization in coal mining to keep up
production as well as its cost at competitive levels.
Due to recent discovery, the coal reserves of Baluchistan have increased from 196mt to 458.2mt. The
present research resulted as grand total reserve of 186,007mt13 coal in Pakistan. Out of these, 7775.5mt13
13Pakistan
Energy Yearbook 2014
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have been measured, 19,412.5mt13 have been indicated and 44,526 mt13 inferred whereas hypothetical
reserves are about 114,293mt13.
Table 19: Coal Reserves of Sindh Province (million tonnes)13
Coalfield
Coal Th.
M.
Ind.
Inf.
Hyp.
Total
Lakhra
0.3-3.3m
244
629
455
-
1328
SondaThatta
0.3-1.5m
60
511
2197
932
3700
Jherruck
0.3-6.2m
106
810
907
-
1823
Ongar
0.3-1.5m
18
77
217
-
312
0.3-2.5m
51
170
1556
-
1777
0.3-1m
10
43
108
-
161
Badin
0.5-3.1m
150
0
200
500
850
Thar
0.222.8m
7025
17130
38650
112700
175505
7664
19370
44290
114132
185456
Indus
East
MetingJhimpir
Total
Moist
.
9.738.1
22.648.0
9.039.5
9.039.5
9.039.5
26.636.6
29.655.5
V.M.
18.338.6
16.136.9
20.044.2
20.044.2
20.044.2
25.2-34
23.136.6
Fix
Carbon
Ash
9.838.2
8.931.6
15.058.8
15.058.8
15.058.8
24.132.2
4.349
2.752.0
5.039.0
5.039.0
5.039.0
8.216.8
14.234.0
2.911.5
T.
Sulphur
H.V.;
BTU/lb
Rank
1.2-14.8
5,503-9,158
LigB-SubC
8,87813,555
8,80012,846
5,21911.172
SubChvBb
SubChvCb
0.4-7.7
7,782-8,660
LigA-SubC
2.9-5.1
7734-8612
LigA-SubC
0.2-15.0
0.4-7.7
0.4-7.7
0.4-2.9
11,41511,521
6,24411,045
LigB-SubA
LigB-SubA
B.4.8.3 Wind Power Potential in Pakistan:
The wind map of Pakistan developed by National Renewable Energy Labs (USA) has identified that wind
with good to excellent speeds is available in many parts of the country, establishing a total potential of
about 340,000 MW (Figure 16). The Gharo - Keti Bandar wind corridor, in the South of Pakistan, having an
approximate potential of 50,000 MW is the most attractive to investors at this point due to good resource
potential as well as its close proximity to major load centres and the national grid. Ground data for other
potential areas in the country is also being gathered and verified.
Figure 16:Wind Potential in Pakistan (Source: AEDB)
B.4.8.4
Solar energy potential in Pakistan:
Pakistan has immense solar resources, suitable for both Photovoltaic (PV) and thermal i.e. Concentrated
Solar Power (CSP) applications. The Annual Direct Normal Solar Radiation (which indicates the potential for
CSP) is in the range of 7 to 7.5 kWh/m2/day in many parts of Baluchistan and between 6.5 to 7 kWh/m2/day
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in other parts of Baluchistan; 5 to 5.5 kWh/m2/day in Southern Punjab and Northern Sindh and around 4.5
to 5 kWh/m2/day in rest of Pakistan. The Annual Flat Plate Tilted at Latitude Solar Radiation, indicates
immense potential for PV, which is in the range of 7 to 7.5 kWh/m2/day in most of Baluchistan; 6 to 6.5
kWh/ m2/day in most of Sindh, Southern Punjab and Gilgit-Baltistan and in the range of 5.5 to 6
kWh/m2/day in rest of the country. Solar map of Pakistan is at Figure 17 below.
Figure 17: Solar Potential in Pakistan (Source: AEDB)
B.4.8.5
Biomass/Bagasse/Waste to Energy potential in Pakistan:
Pakistan produces huge amount of municipal waste (Karachi 9,000 tons/day and other cities about 2,000 to
6,000 tons/day) and agriculture waste in the form of Bagasse, Cotton Sticks and Rice Husk. Converting this
waste to energy can generate upto 3,000 MW of power. Pakistan offers lucrative opportunities in this
sector in which a number of projects are already under preparation.
Pakistan being the agricultural country is having huge prospects for energy plantation i.e. Jatropha Curcas,
Castor, Sukh Chain etc. Around 35 Million Hectares of marginal / degraded land is available in different
parts of the country that is best suited for this purpose.
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Figure 18: Waste to Energy Potential in Pakistan (Source: AEDB)
B.4.8.6
Pakistan Geothermal Potential / Resource
Pakistan also possesses a good regime for Geothermal energy. Many hot water springs, some generating
surface water temperature upto 830C lie in the North of Pakistan. Geothermal sites have also been
identified in Baluchistan and Sindh. Although detailed surveys have not been conducted, it is estimated that
over 2,000 MW of Geothermal resources can be commercially tapped.
B.4.9
Plan to meet the Demand
The GoP has prepared ambitious plans and targets to add to generation capacity of the country to meet
increasing demand. The GoP is seeking private sector investment for enhancement of generation capacity.
The projects that are including as Early Harvest Projects in the China-Pakistan Economic Corridor Planning
that are planned to be executed by 2018-19 are listed below:
•
Coal
:
Gaddani Power Park
Thar Coal
Shaiwal Coal Project (Punjab)
Port Qasim
Jamshore
6600 MW
660 MW
1320 MW
1320 MW
1200 MW
•
Hydel
:
Suki Kinari
Karot
Kohala
Dasu
840 MW
700 MW
1100 MW
4300 MW
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Tarbela 4th Extension
Tarbela 5th Extension
•
•
•
•
1410 MW
1320MW
Wind :
Solar :
Cogeneration
Transmission Line capacity enhancement
1750 MW
1000 MW
1000 MW
B.4.10 Investment Plan for Power Generation Project
The investment plan for power generation projects along with other details for the years to comes, as
provided by the NTDC and PPIB are produced in the following tables respectively.
Table 20: Investment Plans of KESC for Power Generation Projects 14
Capacity
Name of Plant and Location
(MW)
Nuclear Thermal Wind
Total
Year
Cumulative
Existing Capacity
2013-14
2951
137
2814
0
2951
2951
Plan of Capacity Addition
KCCPP Cycle Closing, Korangi
2014-15 Creek
KGTPS Cycle Closing, Korangi
2014-15 Industrial Area
27.5
0
27.5
0
27.5
2978.5
10
0
10
0
10
2988.5
2015-16
10
0
10
0
10
2998.5
SGTPS Cycle Closing, SITE
Table 21: Investment Plan for Power Generation Projects (KESC) (2014-15 to 2016-17)14
S. No.
Name of Project
Capacity
(MW)
Expected
Commissioning
Year
Estimated Cost
27
2014-15
US $ 53 Million
10
2014-15
US $ 40 Million
10
2015-16
US $ 29 Million
KESC's Own Programme
1
2
3
KCCPP Cycle Closing, Lorangi Creek
KGTPS Cycle Closing, Korangi Industrial
Area
SGTPS Cycle Closing, SITE
Plan to induct IPPs in KESC system
Nil
The details of Power plants initiated in the public and private sector are as follows:
Table 22: Investment Plan for Public Sector Power Generation Projects (as per approved PC-I)14
Expected
Commissioning
Year
Estimated Cost
(Million
Rupees)
S. No.
Name of the Project
Capacity (MW)
1
Combined Cycle Power Plant at Nandipur
425
January 2015
58,416
2
747
March, 2015
59,773
1320
December, 2019
177,175
4
Combined Cycle Power Plant at TPS Guddu
Jamshoro Power Generation Project (Coal
Based)
Combined
Cycle
Power
Plant
at
Chickokimallian
525
Not yet firmed up
33,744
5
UAE Gifted Power Plant
320/440
Not yet firmed up
16,348
3
14State
of Industry Report 2014
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Table 203: Upcoming Power Generation Projects as per NTDC
Sr. #
Fiscal
Year
Name of Project
Agency Fuel Capacity (MW) Comissioning Date Addition/ year (MW)
Existing capacity
2013-14
1
2
Guddu (1)
Guddu Steam (2)
GENCOs Gas
GENCOs Gas
243
243
Apr. 2014
May. 2014
4
5
6
3
Quaid-e-Azam Solar Park Phase-1
Guddu Steam (3)
Foundation Wind Energy-2
Quaid-e-Azam Solar Park Phase-2
PPDB
GENCOs
AEDB
PPDB
Solar
Gas
Wind
Solar
100
261
50
300
Sep. 2014
Sep. 2014
Oct. 2014
Dec. 2014
7
8
9
10
11
12
13
Foundation Wind Energy-1
Three Gorges Wind Farm
Nandipur Power project
Sapphire wind
Yunus Energy
United Energy
Metro power
AEDB
AEDB
GENCOs
AEDB
AEDB
AEDB
AEDB
Wind
Wind
Oil
Wind
Wind
Wind
Wind
50
50
425
50
50
100
50
Jan. 2015
Jan. 2015
Mar. 2015
Mar. 2015
Apr. 2015
Apr. 2015
May. 2015
14
15
Tapal Wind Energy Pvt. Ltd.
Sachal Energy
AEDB
AEDB
Wind
Wind
30
50
May. 2015
Jun. 2015
2014-15
2015-16
16
17
18
19
20
Quaid-e-Azam Solar Park Phase-3
JHM-WPP#1
JHM-WPP#2
JHM-WPP#3
JHM-WPP#4
PPDB
AEDB
AEDB
AEDB
AEDB
Solar
Wind
Wind
Wind
Wind
600
50
50
50
500
Sep. 2015
Feb. 2016
Mar. 2016
Apr. 2016
Apr. 2016
21
22
23
24
25
JHM-WPP#5
JHM-WPP#6
JHM-WPP#7
JHM-WPP#8
JHM-WPP#9
AEDB
AEDB
AEDB
AEDB
AEDB
Wind
Wind
Wind
Wind
Wind
50
50
50
50
50
Aug.
Aug.
Sep.
Sep.
Sep.
26
27
28
29
30
31
32
33
34
35
JHM-WPP#10
JHM-WPP#11
JHM-WPP#12
JHM-WPP#13
JHM-WPP#14
JHM-WPP#15
Neelum Jhelum Hydel
Golen Gol HPP
CHASNUPP-III-Punjab
Patrind HPP
AEDB
AEDB
AEDB
AEDB
AEDB
AEDB
WAPDA
WAPDA
PAEC
PPIB
Wind
Wind
Wind
Wind
Wind
Wind
Hydel
Hydel
Nucl
Hydel
50
50
50
50
35
35
969
106
340
147
Oct. 2016
Oct. 2016
Oct. 2016
Nov. 2016
Nov. 2016
Nov. 2016
Nov. 2016
Dec. 2016
Dec. 2016
Dec. 2016
36
37
Phandar Hydro
Tarbela 4th ext.Hydro
WAPDA Hydel
WAPDA Hydel
80
1410
May. 2017
Jun. 2017
38
39
40
41
42
43
Keyal Khwar
CHASHNUPP-IV-Punjab
Engro Thar Coal
Port Qasim PP
Gulpurpoonch river
Dasu-1
WAPDA
PAEC
PPIB
PPIB
PPIB
WAPDA
Hydel
Nucl
Coal
Coal
Hydel
Hydel
122
340
600
1320
100
2160
Oct. 2017
Oct. 2017
Dec. 2017
Dec. 2017
Dec. 2017
Jan. 2018
44
45
CASA
Rajdhani HPP
GoP
Imp.
AJKHEB Water
1000
132
May. 2018
Jun. 2018
2016-17
486
21839
1566
23405
1250
24655
3572
28227
5774
34001
2016
2016
2016
2016
2016
2017-18
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Total Inst.
Cap.
(MW)
21353
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2018-19
46
47
48
TPS Jamshoro (Unit Add.) Phase-1
Sehra HPP
Gaddani (1)
GENCOs Coal
PPIB Hydel
PPIB
Coal
660
130
3300
Sep. 2018
Dec. 2018
Dec. 2018
TPS Jamshoro(Unit Add.) Phase-2
GENCOs Coal
660
Mar. 2019
50
51
Engro Thar Coal
Lower Pallas Valley
PPIB
Coal
WAPDA Hydel
600
665
Dec. 2019
Dec. 2019
52
53
Gaddani (2)
Lower Spat Gah
PPIB
Coal
WAPDA Hydel
3300
496
Dec. 2019
May. 2020
54
55
56
Coastal Karachi (K2)
Karot HPP
Azad Pattan HPP
PAEC
PPIB
PPIB
Nucl
Hydel
Hydel
1100
720
640
Jun. 2020
Jun. 2020
Jun. 2020
Suki Kinari HPP
PPIB
Hydel
840
Jun. 2020
Coastal Karachi (K3)
PAEC
Nucl
1100
May. 2021
49
2019-20
57
2020-21
58
References:
4750
38751
8361
47112
1100
48212
i. As per data provided by WAPDA Hydel, GENCOs, AJKHEB, PPIB and PAEC information
Notes:
i. Tarbela 5th Extension has not been included because its feasibility study is under preparation
ii. Lower Spat Gah and Lower Palas Valley projects are linked with schedule of Dasu due to power evacuation issues.
iii. Gabral Kalam, Kalam Asrit, Asrit Kedam and Madyan are linked with Basha Dam project due to power evacuation issues.
B.4.11 Investment Plan for National Grid Extension
Being National Grid Company of the country, NTDC is solely responsible for overall reliability, planning and
coordination of the electricity transmission in Pakistan except the area under KESC. Further, NTDC is solely
responsible to provide interconnection arrangement to evacuate power from up-coming power projects in
the country. To discharge its responsibility NTDC has prepared an investment plan for improvement of its
transmission network and grid station. The power planning process followed by NTDC is described in below
Figure 19.
Figure 19: Power Grid Planning Process of NTDC (Source: NTDC)
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Power grid planning is based on system studies with the following two key inputs:
- Load Forecast
- Generation Plan
Following grid planning studies are carried out:
- Load Flow
- Short Circuit
- Transient Stability
Power grid planning studies are carried out to keep the following system parameters within the prescribed
criteria set out in Grid Code approved by NEPRA:
- Voltage (+8%/-5% under normal condition and ±10% under N-1 condition)
- Loading of transmission lines (100% under normal & N-1 condition)
- Loading of transformers (100% under normal & N-1 condition)
- System Stability (Permanent 3-phase fault on any transmission line and associated
components cleared in 5-cycles followed by the outage of the associated line and failure
of breaker to clear the fault in 5 cycles (stuck breaker condition) with backup clearing in
9-cycles after fault initiation).
Following tables show the Grid Station and Transmission Expansion Plan of NTDC.
Table 24: Grid Station Expansion Plan of NTDC 15
500/220 kV Grids
Year
Nos
New Grid Station
20143
15
20151
16
201617
Extension
20141
15
15State
220/132 kV Grids
MVA
Capacity
Expected
COD
Estimated
Cost (Rs.
Million)
Nos
MVA
Capacity
Expected
COD
Estimated
Cost (Rs.
Million)
4500
2016-17
22505
6
3750
2016-17
16770
2250
2017-18
5156
4
2750
2017-18
18063
-
-
-
3
1500
2016-17
16857
450
2015-16
1053
1
430
2015-16
844
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Table 25: Power Sector Investment Plan for NTDC Transmission Lines (as per approved PC-I)16
Name of
Project
S NO.
Transmission Lines
Voltage
Level (kV)
Line Length
(km)
Capacity
(MVA)
Expected
Completion Date
Estimated Cost
(million Rs.)
1
Rohri
220
175
500
July, 2014
4,847
2
Kassowal
220
90
320
July, 2014
2,067
3
Okara
220
10
750
1,884
4
IT. Singh
220
2
750
July, 2014 [1 No.
of T/F commissioned on 04-102013)
July, 2014
5
6
220
500
65
60
500
1700
September, 2014
December, 2014
2,633
4,936
7
8
Chistian
Rahim Yar
Khan
Gujrat
SVC at NKLP
220
-
4
-
750
450
December, 2014
December, 2014
1,966
2,087
9
Quetta
-
-
450
December, 2014
2,087
10
Shikarpur
500
84
1200
December, 2014
8,085
11
500
40
1700
April, 2015
4,467
220
5
260
June, 2015
880
13
Dera Ghazi
Khan
Dera Murad
Jamali
Lahore
500
130
1500
December, 2015
12,664
14
15
Ghazi Road
Nowshehra
220
220
80
10
480
750
December, 2015
2015-16
2,592
1,876
16
Lalian
220
8
750
2015-16
1,581
17
Mansehra
220
1
500
2015-16
905
18
500
2015-16
3,744
19
Dera Ismail
220
100
Khan
Augmentation of Existing Grid Stations:
(i)
Rawat
500
-
750
(ii)
220
-
1000
(iii)
Sheikh
Muhammadi
Burhan
220
-
1000
(iv)
Bund Road
220
-
1000
(v)
Mardan
220
-
500
(vi)
(vii)
Bahawalpur
Quetta
Industrial
220
220
-
500
500
12
16State
June, 2015
1,759
3900
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Table 26: Interconnection Arrangement to Evacuate Power from up-coming (Public and Private Sector)
Power Projects17
S No
Name of Power Project
Plant
Capacity
MW
Expected
COD
1.
Power Dispersal from Chashma
Nuclear Power Project (C3 and C4)
2.
Power Dispersal from 747 CCPP
at Guddu)
3.
2x340
2015-16
747
2015-16
Power
Dispersal
from Uch-II
2015-16
4.
3rd Circuit (for Power Evacuation
from 2x660 MW Coal Fired Power
Plants at Jamshoro and Dispersal of
Wind Power)
2270
2016-17
5.
Power Dispersal from Neelum
Jhelum, Azad Pattan and Karot
Hydropower Projects
969+650+
720=2339
2016-17
6.
Power Dispersal from Thar Coal
based Power Plant
1200
2016-17
7.
Evacuation of Power from 1000
100
2014-15
17State
Proposed Transmission Scheme
220 kV Chashma Nuclear - Bannu
D/C T/L (125 km)
220 kV D/C T/L for in/out of existing
Cl and C2 at C3 and
C4 (2 km)
Extension at 220 kV Bannu
500 kV Guddu-Muzaffargarh S/C T/L
(256 km)
Two 500 kV T/L for in/out of 500 kV
Guddu-Multan S/C
T/L at 500 kV Muzaffarqarh (10 km)
Extension at 500 kV Muzaffargarh
220 kV Uch-II - Sibbi D/C T/L (125
km)
220 kV D/C T/L for in/out of 200 kV
existing Uch-I to
Shikarpur New S/C T/L at Uch-II (0.5
km)
Reconductoring of 220 kV T/L Uch-I
to Uch-II (I km)
Extension at 220 kV Sibbi
Substation
500 kV Jamshoro-Moro-RYK S/C T/L
(535 km)
500 kV Moro-Dadu S/C T/L (55 km)
500 kV Switching Station at Moro
Extension at 500 kV Jamshoro,
Dadu and RYK Grid Stations
500 kV D/C T/L from Neelum
Jhelum to Domali (145 km)
500 kV D/C T/L from Domali to 500
kV Gujranwaia Grid Station (130
km)
Extension at 500 kV Gujranwaia
(two lines bays with 3x37
MVA Shunt Reactors)
500 kV D/C T/L for in/out of 500 kV
Neelum Jhelum
Gujranwaia S/C at Azad Pattan (5
km)
500 kV D/C T/L for in/out of 500 kV
Neelum Jhelum
Gujranwaia S/C at Karot (5km)
500 kV Thar - Matiari D/C T/L (250
km)
500 kV Switching Station at Matiari
Phase I:
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MW Quaid-e-AzamSolar Park at LalSuhanra
8.
Evacuation of Power from Wind
Power Projects at Jhimpir and
Gharo Wind Clusters
132 kV D/C T/Ls (4 km)
300
2014-15
Phase II:
132 kV D/C T/Ls (52 km)
600
2015-16
330
2015-16
620
2016-17
Phase III:
220 kV Grid Station at Lal-Suhanra
with 3x250 MVA,
220/132 kV transformers along
with allied equipment
and accessories
220 kV D/C T/L from 220 kV LalSuhanra to 220 kV
Bahawalpur (40 km)
Three 132 kV D/C T/Ls on Rail
Conductor form Solar
Projects Sites to 220 kV Grid Station at
Lal-Suhanra (8 km
each)
Phase I:
132 kV Jhimpir New Collector
Substation
132 kV D/C T/Lines (107 km)
Phase II:
Upgradation of 132 kV Jhimpir
Substation to 220 kV Substation
(3x250 MVA)
220 kV Gas Insulated Substation
(GIS) at Gharo (2x250 MVA)
220 kV D/C T/Lines (155 km)
500
2016-17
132 kV D/C T/Lines (85 km)
Addition of 450 MVA, 500/220
kV T/F at 500 kV Jamshoro
Phase III:
220 kV D/C Line (10 km)
From above, the unique features of the Power Sector in Pakistan can be stated below:
 64.4%18 of total electricity supply is dependent on fossil fuels; 80% of the fuel requirements to run
these plants are met through imported fuel that is a huge burden on country’s economy.
 The flow of electricity in Pakistan is from North to South as Most of the power plants are located on
North and central part of the country. A huge electricity loss is incurred while transmitting the
electricity from power plants to the load centres in south.
 Pakistan is an energy starved country. There is a deficit of more 5000 MW between the power
supply and the controlled electricity demand that is pushing to carry out load-shedding for 4-6
hours/day. This is causing a huge economic loss to the economy.
 Grid infrastructure is outdated and requires strengthening.
Exploiting wind energy is deems to be very beneficial for Pakistan considering the facts that:
 Wind energy is a clean source of energy that has definite prospects of reducing Green House Gases
(GHGs). It is estimated that the planned wind power project will generate 274,500 MWh of
electricity annually, that would replace such amount of electricity generated from fossil fuel based
thermal power plants and hence would contribute towards reducing emissions of GHGs.
18Pakistan
Energy Year Book 2014
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 Availability of power would result in meeting electricity demand. This would add to the economic
benefit of the country.
 Availability of power would also enable social uplift of the people residing in the project site which is
the remotest part of the country
B.5. Demonstration of additionality
In line with ACM0002 (version 16), the Tool for the demonstration and assessment of additionality (version
07.0.0) was used to demonstrate that the project is additional. The following steps were undertaken:
Step 1: Identification of alternatives to the project activity consistent with current laws and regulations
Sub-step 1a: Define alternatives to the project activity:
The following are identified the alternatives to the project activity:
Alternative 1: The project activity not undertaken as a CDM project activity
Alternative 2: A fossil fuel based power plant producing electricity with comparable quality, properties and
application areas (e.g. Refused Derived Fuel / High Speed Diesel Plant). This alternative is considered
credible because fossil fuel based power plants have already been implemented in Pakistan by Independent
Power Producers. More recently, another IPP, Nandipur Power, has commissioned a fossil fuel / HSD based
power plant with a capacity of 100 MW. Plans are also underway to develop 6,600 MW coal fired power
plant in different parts of the country. The government has announced very lucrative incentives for coal
power plants including levelized upfront tariff of US Cents 8.5/kWh with guaranteed Return on Equity of
27%, whereas wind power project IPPs are allowed 17% Return on Equity in wind Upfront Tariff. The
government is investing in developing infrastructure required to execute, operate and maintain these
power plants, and evacuate power generated through these projects. Private sector companies are
showing great interest because of preferential incentives announced for developing coal power plants. Due
to this, coal power plants are becoming as investors’ first choice. Moreover, coal fired and other thermal
power plants are preferred by the government as these are considered as the ‘baseload’. The interest and
desire of the government to develop wind power is lesser as compared to other thermal based power
plants.
Alternative 3: A power plant using another source of renewable energy and producing electricity with
comparable quality, properties and application areas (e.g. solar and biomass). This alternative is considered
credible because (i) Interest is being sought to develop biomass based power plants. It has to be noted that
biomass based power production is heavily reliant on the availability of sufficient quantities of feedstock.
Therefore, the development of a biomass based power project is probably a more credible scenario for
agricultural companies (like sugar companies) that own a lot of agricultural waste and less so for a project
developer without direct access to such biomass feedstock. Sugar industries in Pakistan under special policy
framework and set of incentives announced by the government are developing their capacities to install
bagasse based power plants. They are upgrading their current boilers to high pressure boilers and would be
generating power more than their requirements. The extra generated electricity would be purchased by the
government at a lucrative tariff that would ensure 18% Return on Equity to the developers. (ii) The
government is much ambitious to harness solar energy potential in the country. In this regard, the
government has announced to develop 1000 MW solar power projects in Cholistan, Punjab Province. 100
MW out of which is being developed by the government itself, whereas for remaining, the government has
allocated land at concessional rates, grid infrastructure and site access infrastructure is being developed
and IPPs are guaranteed 18% of Return on Equity.
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Large hydro projects are also considered as alternative because the country is aiming to install more
hydropower projects through private sector participation.
Alternative 4: Electricity generated by the operation of grid-connected power plants and by the addition of
new generating sources. This, in fact, is the continuation of the current situation and is the identified
baseline for the installation of a new grid-connected renewable power plant according to ACM0002
(version 16).
Sub-step 1b: Consistency with mandatory laws and regulations:
All the above alternatives are consistent with mandatory and regulatory requirements, especially the
NEPRA Act (1997) and related power policies of the government that allows for Independent Power
Producers to supply electricity to the national grid through a Power Purchase Agreement with the National
Transmission and Despatch Company (NTDC). There are no restrictions on types of power plants, hence,
both fossil fuel based power plants and renewable energy power plants are allowed to deliver electricity to
the grid. Because the alternatives identified are in compliance with all applicable laws and regulations and
are also realistic and credible alternatives available to the project participants, the project is additional
under step 1.
Step 2: Investment analysis
Taking into account the Guidelines on the assessment of investment analysis (version 05), the following
steps were taken.
Sub-step 2a: Determine appropriate analysis method
The Tool for the demonstration and assessment of additionality provides three methods for carrying out
investment analysis:
Simple cost analysis (Option I),
Investment comparison analysis (Option II)
Benchmark analysis (Option III).
The proposed project activity will generate financial and economic benefits other than CDM related income
therefore the simple cost analysis (Option I) cannot be applied. In line with ACM0002 (version 16), the
baseline scenario for the project activity is the supply of electricity from a grid. Therefore, the baseline
scenario does not necessarily require investment and is outside the control of the project developer.
Option III, benchmark analysis is, therefore, selected as the appropriate analysis method for the project
activity.
Sub-step 2b: Option III. Apply benchmark analysis
In line with paragraph 12 of the Guidelines on the assessment of investment analysis (version 05), the
average cost of equity for renewable energy investments in Pakistan was used as the appropriate
benchmark for comparison with the Equity IRR. The project has calculated the EIRR based on the CDM
default value from the Guidelines on the assessment of investment analysis (version 5) for equity return of
renewable energy investments in Pakistan.
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All input values used in the investment analysis were valid and applicable at the time the investment
decision was taken. The post-tax cash-flow analysis is carried out in nominal terms. The average cost of
equity was calculated using the formula below:
Ke nominal = Kereal+i
Where:
Ke
i
=
=
Average cost of equity financing
Pakistan’s inflation forecast
The following nominal values were used to determine the average cost of equity:
Parameter
Value
Unit
Kereal
14.7
%
i
3.5
%
Source
CDM default value from the Guidelines on the assessment of
investment analysis (version 5)
Pakistan inflation target published by Pakistan Bureau of
Statistics
Based on the above parameter values, the average cost of equity is calculated as follows:
Ke = 14.7% + 3.5% = 18.2%
Sub-step 2c: Calculation and comparison of financial indicators:
Basic parameters and assumptions used for the calculation of the Equity IRR are given in the tables below:
Table 27: Project Parameter
Project Parameter
Wind Turbines
Number of Turbines
Turbine Capacity
Gross Capacity
Net Energy Production
(P90)
Plant Load Factor
Exchange rate PKR/USD
Corporate Tax
Value
General Electric GE
1.7-103
29
1.7
Unit
Source
Type
Financial model
Unit
MW
Financial model
Financial model
49.3
MW
Financial model
180,687
MWh
Financial model
41.253
%
105
PKR/USD
0
%
Financial model
State
Bank
of
Pakistan
20/14/16www.sbp.gov.pk
Income Tax ordinance 2001
Table 28: Capital Cost
No.
1
2
3
4
5
6
7
8
9
Version 06.0
Cost Head
EPC Cost
Duties and Taxes
Total EPC Cost
Non-EPC Cost
Project Development Cost
Pre-COD Insurance
Financial Charges
Interest during Construction
Debt Service and Other Reserves
Working Capital and Contingencies
Total Project Cost
Value in US $
95,000,000
2,600,355
97,600,355
1,083,625
9,834,956
1,282,500
3,784,608
3,824,159
6,368,906
3,268,750
127,047,859
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Table 29: O&M Cost
Cost Head
Company O&M Expenses (incl.
corporate cost) p.a.
Insurance during O&M
Sub Total
Year 01-02
3,100,000
Year 03-05
2,810,000
Year 06-10
3,000,000
All values in US $
Year 11-20
3,130,000
1,120,000
4,220,000
1,120,000
3,930,000
1,120,000
4,120,000
1,120,000
3,230,000
Table 30: Debt Servicing
No.
1
2
3
4
5
6
7
8
9
Description
Value
Total Project Value
Total value of Debt @ 75% of total Project Value
LIBOR 3-month
Spread
Debt Mark Up
Loan Tenure
Repayment Period
Grace Period
Re-Payment Schedule (Principal and Mark Up)
127.05Mn
95.3Mn
0.5%
4%
Variable
11.5 years
10 years from CoD
18 months
Not Yet Finalized
Table 31: Expected Revenue
Revenues
Value
Sales of Electricity
Tariff
Total Revenue from Electricity
Sales
Unit
Source
180,687
10.4482
MWh/year
USD/kWh
22,000,000
USD/year
Financial model
Upfront Tariff
A 20-year cash flow was used to calculate the Equity IRR in line with the guidance on investment analysis.
The table below shows the Equity IRR calculated for the project with and without CDM. As can be seen
from the table, the CDM project activity without CER revenues has a less favourable Equity IRR than the
benchmark.
Table 28: Equity IRR and Benchmark
Equity IRR and Benchmark
Equity IRR without CDM Revenues
14.7%
Equity IRR with CDM Revenues
17%
Benchmark
18.2%
Sub-step 2d. Sensitivity analysis:
In order to show that the conclusion regarding the financial/economic attractiveness is robust to
reasonable variations in the critical assumptions, a -10%/+10% sensitivity analysis was carried out on the
following parameters:
 Electricity generation
 Capital Costs
 Operating Costs

The table and graph below give an overview of the resulting Equity IRRs.
Table 29: Sensitivity analysis (-10%/+10%)
-10.00%
-5.00%
0.00%
Sensitivity Analysis @ P90
5.00%
10.00%
Electricity Generation (GWH)
162.62
171.65
180.69
189.72
198.76
Capital Costs (US$) in Million
114.78
120.91
127.05
133.19
139.32
Operating Costs (US$) in Million p.a
3.6
3.8
4
4.2
4.4
IRR
12.83%
13.82%
14.74%
15.56%
16.33%
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As can be seen from Table 29, the sensitivity analysis consistently supports (for a realistic range of
assumptions) the conclusion that the project activity is unlikely to be financially/economically attractive
without the revenues from the carbon credits.
Outcome of Step 2: The Benchmark Analysis and Sensitivity Analysis show that the project activity is not
financially attractive without the CER revenue. Therefore, the project activity is additional under step 2
Step 4: Common practice analysis
Sub-step 4a: Analyse other activities similar to the proposed project activity:
The following steps were undertaken to prove that the project activity is not common practice analysis:
STEP 1: The installed capacity of the project activity is 49.3 MW. Therefore, the applicable output range
equalsupto25 MW to 75 MW (+/-25% of the project capacity).
STEP 2: The applicable geographical area is Pakistan. The number (Nall) that deliver the same capacity,
within the range calculated in step 1, as the project activity and have started commercial operations before
the start date of the project activity (April, 2016) equals six (6).
Table 30: Common Practice Analysis
Sr. No.
1
2
3
4
5
6
Power Plant Name
GTPS Shahdra
TPS Quetta
GTPS Panjgur
Altern Energy
FFC Energy Limited
ZorluEnerji (Pvt) Ltd
Date of
Commissioning
Aug-1969
Nov 1994
NA
June 2001
Nov-2012
July-2013
Technology
Sub Critical Thermal
Open Cycle Gas Turbine
NA
Gas Engine
WTG
WTG
Fuel
GAS & HSD
Gas
Gas
Gas
Wind
Wind
Installed Capacity
MW
59
35
39
31
49.5
56.4
STEP 3: The total number of plants (Ndiff) identified under Step 2 that apply a different technology from the
project activity equals four (4).
STEP 4: F = 1 – Ndiff/Nall = 1 – 4/6 = 0.3
Similar activities cannot be observed as Nall – Ndiff is smaller than 3. Therefore, it can be concluded that the
project activity is also additional under step 4 (Common Practice Analysis).
B.6.
Emission reductions
B.6.1. Explanation of methodological choices
Project emissions
Project emissions are calculated using equation 1 in ACM0002 (version 16) shown below:
PEy=PEFF,Y + PEGP,y+ PEHP,y
Where:
PEy
PEFF,y
PEGP,y
=
=
=
PEHP,y
=
Version 06.0
Project emissions in year y (tCO2e)
Project emissions from fossil fuel consumption in year y (tCO2)
Project emissions from the operation of geothermal power plants due to the
release of non-condensable gases in year y (tCO2e)
Project emissions from reservoirs of hydro power plants in year y (tCO2e)
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The project is not a geothermal or solar thermal project that uses fossil fuel. Therefore, PEFF,y = 0
The project is not a hydro power project. Therefore, PEHP,y= 0
The project is not a geothermal project. Therefore, PEGP,y = 0
Therefore, in line with ACM0002 (version 16), project emissions for the project activity are zero.
Baseline Emissions
The baseline emissions (BEy) in year y are calculated using equation 6 shown below:
BEy= EGPJ,yx EFgrid,CM,y
Where:
BEy
EGPJ,y
=
=
EFgrid,CM,y
=
Baseline emissions in year y (tCO2)
Quantity of net electricity generation that is produced and fed into the grid
as a result of the implementation of the CDM project activity in year y (MWh)
Combined margin CO2 emission factor for grid connected power generation
in year y calculated using the latest version of the "Tool to calculate the
emission factor for an electricity system" (tCO2/MWh)
The project activity is a greenfield renewable energy power plant and involves the installation of a new
grid-connected renewable energy power plant/unit at a site where no renewable power plant was
operated prior to the implementation of the project activity. Therefore, option (a), equation 7 is used to
estimate EGPJ,y
EGPJ,y = EGfacilty,y
Where:
EGPJ,y
=
EGfacilty,y
=
Quantity of net electricity generation that is produced and fed into the grid
as a result of the implementation of the CDM project activity in year y (MWh)
Quantity of net electricity generation supplied by the project plant/unit to
the grid in year y (MWh)
The combined margin CO2 emission factor for the Pakistani electricity grid (EFgrid,CM,y) was calculated
using the Tool to calculate the emission factor for an electricity system (version 05.0.0). The following steps
were taken:
Calculations for Baseline Carbon Emissions from Power Sector
Baseline Emission scenario is very prudent to determine when it is required to calculate total emissions of
GHGs from the sector and strategize to reduce or abate those emissions. Globally, power sector is
considered as major source of GHG emissions in most of the countries because of higher reliability on fossil
fuel based thermal power generation. The overall global electricity generation mix indicates that share of
thermal power generation is 66%19 i.e. coal (39%), followed by gas (22%), and oil (5%). By deploying cleaner
energy technologies like ARE, it is possible that GHG emissions can be possibly reduced. In order to make an
energy policy with a target to reduce GHG emissions and devising an environmental strategy to undertake
GHG mitigation activities, it is prudent to accurately forecast GHG emissions from fossil fuel power plants.
The accurate forecasting of carbon dioxide (CO2) emissions from fossil fuel energy consumption is a key
requirement for making energy policy and environmental strategy.
19The
World Bank-World Development Indicators
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Figure 20: World Electricity Production from All Energy Sources
UNFCCC is emphasizing that all countries to undertake increased mitigation efforts and commit targets for
emissions reductions. Though, the developed nations are planning to invest more in GHG emissions
reduction initiatives, there is a potential to reduce large quantum of GHG emissions if major GHG emissions
contributing sectors in the developing countries like Pakistan are encouraged to shift to ARE technologies.
The countries of the region like India, China, Thailand, Malaysia, Indonesia, Iran etc. have taken several
initiatives to harness ARE technologies and contribute towards mitigating GHGs. Most of the countries of
the world have established baseline emissions factor and accordingly devising policies and strategies to
bring the emissions level down from the baseline.
At present, the national baseline carbon emission factor for Pakistan is not determined. Under the scope of
this paper, data has been collected and analysis has been made regarding power generation plants in
Pakistan, their efficiencies and fuel consumptions to determine baseline emission factor of the country.
This emission factor can be used by the power plants while developing their project documents and
calculating the ability of the plant to generate CERs under CDM. This work can be helpful in reducing the
time that the project owners have to spend while establishing the baseline scenario.
Data Collection
Data collection was the first important task for this research. The input data for calculation of the base line
emissions factor includes the electricity generation from each fuel type, total fuel consumption, Low
Heating Values (LHV), Gross Calorific Values (GCV) of each fuel and Effective CO2 Emissions Factor of each
fuel. The values for the electricity generation from each fuel type, total annual fuel consumption and GCV
are taken from Pakistan’s Energy Year Book for the years 2012, 2013 and 2014 published by Hydrocarbon
Development Institute of Pakistan (HDIP), whereas the values for LHV and Effective CO2 Emission Factor of
each fuel are taken from the IPCC methodologies published in 2006.
The number of CERs by a project is regarded as the quantum of Carbon Credits that the project can earn as
per UNFCCC guidelines. These Carbon Credits can then be sold to international carbon markets and earn
revenue. The financial return gained through this can help in reducing the technical, technological and
financial barriers in executing such projects.
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Procedure to Determine Baseline Emission Factor
The calculations for determining the baseline emission factor were carried out based upon the two
methodological tools of CDM Executive Board. Following six steps were undertaken while calculating the
Baseline Emission Factor as per IPCC methodologies:
STEP 1: Identify the relevant electric power system.
STEP 2: Select an operating margin (OM) method.
STEP 3: Calculate the operating margin emission factor according to the selected method.
STEP 4: Identify the cohort of power units to be included in the build margin (BM).
STEP 5: Calculate the build margin emission factor.
STEP 6: Calculate the combined margin (CM) emissions factor.
The details of these steps are further described below:
Step 1: Identify the relevant electric power system:
As a first step, the electricity system connected to the power plants all over the country was defined. The
boundary was fixed for whole of Pakistan. While doing so, it was noted that the grid operations at all levels
in Karachi Metropolitan city are being managed and operated by KESC which is a private sector entity and
rest of Pakistan is being managed and operated by PEPCO through nine public sector DISCOs. KESC is an
independent organization that is responsible for generation and distribution of electricity within the
Karachi Metropolitan city territory. Main electricity generation within KESC grid comes from natural gas
(NG) and high speed diesel (HSD) based thermal power plants. The KESC is also being supplied with 700
MW through the NTDC grid. The electricity supplies to NTDC grid is being generated through various fuels
like fossil fuels (i.e. Refused Fuel Oil (RFO), HSD and NG), hydel, nuclear, coal etc. Since, the electricity
supplies to KESC grid system and NTDC/DISCOs system have different fuel mix and as both are parallel
integrated entities in this paper two scenarios have been visualized to calculate the grid emissions factor
for Pakistan (i) electric power system with KESC grid and (ii) electric power system without KESC grid.
Step 2: Select an operating margin (OM) method:
Taking into account the grid system in Pakistan, current energy scenario in the country and the data
collected for net electricity generation and fuel consumption, simple OM method has been used for
calculation of the operating margin emission factor (EFgrid,OM,y). This resulted in determining the CO2
emissions factor(s) for net electricity (EFgrid) on the grid from a connected electricity system within the
country.
Step 3: Calculate the operating margin emissions factor according to the selected method:
Low-cost/must-run resources constitute less than 50 per cent of total grid generation (excluding electricity
generated by off-grid power plants) in: 1) average of the five most recent years, and the average of the five
most recent years shall be determined by using one of the approaches described below; or 2) based on long
term averages for hydroelectricity production (minimum time frame of 15 years).
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Here total annual generation of Solar, Wind & Hydel is divided by Total Thermal Generation to calculate
ShareLCMR
Total Thermal Generation =66706.6 GWh
Total Solar+Wind+Hydel Generation =32170.05 GWh
ShareLCMR = 0.48
Since the ShareLCMR <50% So Simple OM is being calculated
The simple OM emissions factor is calculated as the generation-weighted average CO2 emissions per unit
net electricity generation (tCO2/MWh) of all generating power plants serving the national system, not
including low-cost / must run power plants The calculation was done based on data on fuel consumption
and net electricity generation of each power plant. Following formula was used to calculate the simple OM
emissions factor:
𝐸𝐹𝑔𝑟𝑖𝑑, 𝑂𝑀𝑠𝑖𝑚𝑝𝑙𝑒, 𝑦
∑𝑖,𝑚 𝐹𝐶𝑖, 𝑚, 𝑦 X 𝑁𝐶𝑉𝑖, 𝑦 X 𝐸𝐹 𝐶𝑂2, 𝑖, 𝑦
=
∑𝑚 𝐸𝐺𝑚, 𝑦
(1)
Where: EFgrid,OMsimple,yis simple operating margin CO2 emissions factor in year y (tCO2/MWh), FCi,m,y is
amount of fossil fuel type iconsumed by power plant m in year y (mass or volume units), NCVi,y is Net
calorific value (energy content) of fossil fuel type iin year y (Joules(J) / mass or volume unit), EFCO2,i,y is CO2
emissions factor of fossil fuel type iin year y (tCO2/Giga Joules (GJ)), EGm,y is net electricity generated and
delivered to the grid by power plant / unit m in year y (MWh), m is all power plants serving the grid in year
y except low-cost / must-run power plants, i is all fossil fuel types combusted in power plant / unit m in year
y, y is either the three most recent years for which data is available at the time calculating baseline
emissions factor or the applicable year during monitoring (ex post option).
Two separate scenarios are taken for calculations of Simple OM as indicated in Step 1 above.
The calculation to determine Simple OM includes computing NCV by multiplying the LHV of each fuel by its
GCV, Fuel Heat of each fuel by multiplying its NCV with total annual consumption, Grid Emissions from each
fuel type by multiplying its Fuel Heat values with Effective CO2 Emission Factor of each fuel, this value is
divided by total electricity generated annually from each fuel to determine Grid Cumulative Emission Factor
(CEF) or Simple OM value.
Step 4: Identify the cohort of power units to be included in the build margin:
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The set of power capacity additions in the electricity system that comprise 20% of the system generation (in
MWh) and that have been built most recently are taken into account while calculating the emission factor
as per the guidelines of IPCC.
Step 5: Calculate the build margin emission factor:
The build margin emissions factor is the generation-weighted average emission factor (tCO2/MWh) of all
power units m during the most recent year y for which power generation data is available. This is calculated
as follows:
𝐸𝐹𝑔𝑟𝑖𝑑, 𝐵𝑀, 𝑦
=
∑𝑚 𝐸𝐺𝑚, 𝑦 X 𝐸𝐹 𝐸𝐿, 𝑚, 𝑦
∑𝑚 𝐸𝐺𝑚, 𝑦
(2)
Where: EFgrid,BM,y is Build margin CO2 emission factor in year y (tCO2/MWh), EGm,y is net quantity of
electricity generated and delivered to the grid by power unit m in year y (MWh), EFEL,m,yis CO2 emission
factor of power unit m in year y (tCO2/MWh), m is power units included in the build margin, y is most
recent historical year for which power generation data is available.
In order to calculate BM, the IPCC guidelines require taking either five recently constructed power plants or
20% of the national generation capacity, whichever is greater. We adopted the latter option as this gives
the greater value. The Net Electricity Generation and Plant Efficiencies are taken from Pakistan’s Energy
Year Book for the years 2012, 2013 and 2014, whereas Emission Factors of each fuel are taken from the
IPCC guidelines. The product of generated electricity and Fuel Emission Factor is used to calculate CO2
Emissions which are then divided by Net Electricity Generation from each plant to calculate Grid Emission
Factor and Certified Emission number (CE).
Table 21: List of power plants included in the build margin emission factor
Step 6: Calculate the combined margin emissions factor
The combined margin emissions factor is calculated as follows:
EFgrid,CM,y =EFgrid,OM,yX W CM X EF grid, BM,yX W BM
(3)
Where: EFgrid,CM,y is Combined Margin CO2 emission factor in year y (tCO2/MWh), EFgrid,BM,y is Build Margin
CO2 emission factor in year y (tCO2/MWh), EFgrid,OM,y is Operating Margin CO2 emission factor in year y
(tCO2/MWh), wOMis Weighting of Operating Margin emissions factor (%),WBM is Weighting of Build Margin
emissions factor (%)
The following default values are to be used for WOM and WBM as per the IPCC guidelines:
• Wind and solar power generation project activities: WOM = 0.75 and WBM = 0.25 (owing to their
intermittent and non-dispatchable nature) for the first crediting period and for subsequent
crediting periods.
• All other projects: WOM = 0.5 and WBM = 0.5 for the first crediting period ,
Henceforth, the Simple OM / CEF value calculated in Step 4 above is multiplied with 0.75 and the BM / CE
values calculated in Step 5 above are multiplied with 0.25. Both are added to give CM for HAWA Energy
Wind Power Project.
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Leakage
No leakage emissions are considered. The main emissions potentially giving rise to leakage in the context of
electric sector projects are emissions arising due to activities such as power plant construction and
upstream emissions from fossil fuel use (e.g. extraction, processing, and transport). These emissions
sources are neglected.
Emission reductions
Emission reductions are calculated as follows:
ERy=BEy- PEy
Where:
ERy
BEy
PEy
=
=
=
Emission reductions in year y (tCO2e)
Baseline emissions in year y (tCO2)
Project emissions in year y (tCO2e)
Since the project emissions (PEy) is equal to zero.
ERy=BEy
B.6.2. Data and parameters fixed ex ante
Data / Parameter
Unit
Description
Source of data
Value(s) applied
Choice of data or Measurement methods and
procedures
Purpose of data
Additional comment
Data / Parameter
Unit
Description
NCVi,y
GJ/kg
Net calorific value (energy content) of fossil fuel type iin
year y
IPCC default values at the lower limit of the uncertainty at a
95% confidence interval as provided in Table 1.2 of
Chapter 1 of Vol. 2 (Energy) of the 2006 IPCC Guidelines on
National GHG Inventories
See Appendix 4
No data on NCV is available from power generation plants.
IPCC values will be checked annually to ensure the latest
version of the values is used. All data collected as such will
be archived electronically and be kept at least for two years
after the end of the last crediting period.
Calculation of baseline emissions
-
Purpose of data
EFCO2,i,y
tCO2/GJ
CO2 emission factor of fossil fuel type iin year y
IPCC default values at the lower limit of the uncertainty at a
95% confidence interval as provided in table 1.4 of Chapter
1 of Vol. 2 (Energy) of the 2006 IPCC Guidelines on National
GHG Inventories.
See Appendix 4
No data is available from power generation plants. IPCC
values will be checked annually to ensure the latest version
of the values is used. All data collected as such will be
archived electronically and be kept at least for two years
after the end of the last crediting period.
Calculation of baseline emissions
Additional comment
-
Source of data
Value(s) applied
Choice of data or Measurement methods and
procedures
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Data / Parameter
Unit
Description
Source of data
Value(s) applied
Choice of data or Measurement methods
and procedures
Purpose of data
Additional comment
Data / Parameter
Unit
Description
Source of data
Value(s) applied
Choice of data or Measurement methods
and procedures
Purpose of data
Additional comment
EGm,y
MWh
Net quantity of electricity generated and delivered to the
grid by power unit m in year y
National Transmission and Despatch Company (NTDC) /
National Electric Power Regulatory Authority (NEPRA)
See Appendix 4
Data is obtained directly from NTDC which is the utility in
charge of electricity distribution in the country and NEPRA
which is the electricity regulatory of the country
Calculation of baseline emissions
Applicable to the grid emission factor calculations in
particular the build margin
FCi,m,y
Mass or volume unit
Amount of fossil fuel type iconsumed by power plant/unit
m in year y
The NEPRA in its tariff determinations for power plants
provides approved specific fuel consumption data for
thermal power plants. These data are provided in kg/kWh
and are used by NTDC to calculate the fuel charges on the
electricity bills. The data can be converted to mass unit by
multiplying the values in kg/kWh by the annual electricity
generation for the power plant.
See Appendix 4
Data is obtained directly from the NEPRA and the Energy
Year Books published by Government of Pakistan for the
year 2011, 2012, 2013 & 2014
Calculation of baseline emissions
Applicable to the grid emission factor calculations in
particular the build margin
B.6.3. Ex ante calculation of emission reductions
The emission reductions of the project activity are calculated as follows:
ERy=BEy- PEy
Since the project emissions (PEy) is equal to zero.
ERy=BEy
The baseline emissions are calculated using the following formula:
BEy= EGPJ,yx EFgrid,CM,y
Average future quantity of net electricity generation supplied by the project activity to the grid in year y
(MWh/yr) is estimated to be 180,687 MWh.
The combined margin emission factor for the grid is calculated using the following formula:
EFgrid,CM,y= EFgrid,BM,yx WBM + EFgrid,OM-DD,yx WOM
Values to determine EFgrid,CM,y
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EFgrid,BM,y
WBM
EFgrid,OM-DD,y
WOM
=
=
=
=
0.280 tCO2/MWh
0.25
0.658 tCO2/MWh
0.75
EFgrid,CM,y
=
0.563 tCO2/MWh
BEy
=
180,687 * 0.563 = 101,727 tCO2/year
ERy = BEy
=
101,727 tCO2/year
Therefore:
More detailed and transparent calculations can be found in the spreadsheet attached to this PDD
B.6.4. Summary of ex ante estimates of emission reductions
Year
Baseline emissions
(t CO2e)
2018
2019
2020
2021
2022
2023
2024
101,727
101,727
101,727
101,727
101,727
101,727
101,727
Total
Total number of
crediting years
Annual average
over
the
crediting period
713,352
Project emissions
(t CO2e)
-
101,727
-
B.7.
Leakage (t CO2e)
Emission reductions (t
CO2e)
-
101,727
101,727
101,727
101,727
101,727
101,727
101,727
-
101,727
713,352
7
Monitoring plan
B.7.1. Data and parameters to be monitored
Data / Parameter
EGfacility,y and EGPJ,h
Unit
MWh
Quantity of net electricity generation supplied by the project plant/unit to the
grid in year y and hour h
Main and backup metering equipment installed at project activity site in line with
the provisions of the Energy Purchase Agreement (EPA) and the Pakistan
National Grid Code
Year
Electricity Generation (MWh)
2018
180,687
2019
180,687
2020
180,687
2021
180,687
2022
180,687
2023
180,687
2024
180,687
Hourly data
20.9
The net quantity of electricity generated is metered on site using the main
metering system (SCADA controls and communication) and quantified in
Description
Source of data
Value(s) applied
Measurement methods
and procedures
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Purpose of data
generation data and power export invoices to NTDC. HAWA shall install a data
recorder and shall make a continuous recording of the Net Electrical Output.
Such Net Electrical Output shall be recorded on appropriate magnetic media or
equivalent. The metering shall register per measurement period the following
data: per kWh and kVArh the delivered energy and reactive power and the
metering period. The data shall be stored in long-term data storage. All data shall
be transferred to the meter data buffer and to the SCADA systems of both NTDC
and HAWA.
The quantity of electricity supplied to the grid will be measured continuously and
recorded monthly. The basic measurement period shall be carried out in line with
EPA. The Metering System shall be read monthly on the last day of each month
(or such other day as may be agreed upon by the parties) for the purpose of
determining the Net Electrical Output of the Plant since the preceding reading.
HAWA shall read the Metering System by reading the log in the SCADA system
and taking the kWh meter position on the first day of the calendar month at 0:00
mid-night. HAWA shall verify the same through their SCADA system.
The main metering requirements according to the EPA and National Grid Code of
Pakistan will be met. The equipment will also comply with international
standards. Any programmable settings available within a metering installation,
data logger or any peripheral device, which may affect the resolution of
displayed or stored data, shall meet the relevant requirements of EPA. The
method of calibration and frequency of tests shall be agreed between HAWA and
NTDC based on requirements outlined in the Pakistan Grid Code. The meters will
have a fixed seal not to be broken by the project proponent. Reconciliation of
data with backup metering system will be done as needed. This data will be
double-checked with receipt of sales/invoices from NTDC. In case of any
difference, the most conservative (i.e. lower) value of both the invoice and the
meter reading value will be used for the purpose of calculating the emission
reductions. Photographic facilities will also record the metered data as part of
monthly onsite verification procedures. In order to ensure conservativeness,
Non-Project Missed Volume (electrical energy not delivered to the grid due to
NTDC system interruption) will not be included in emission reduction
calculations.
Calculation of baseline emissions
Additional comment
-
Data / Parameter
FCi,n,y
Unit
Description
Mass or volume unit
Amount of fossil fuel type iconsumed by power plant n in year y
The tariff determinations of National Electric Power Regulatory Authority
(NEPRA) in respect of thermal power plants and recorded in the State of Industry
Reports published by NEPRA on annual basis provides approved specific fuel
consumption data for thermal power plants. These data are provided in kg/kWh
and are used by NTDC to calculate the fuel charges on the electricity bills of the
consumers. The data can be converted to mass unit by multiplying the values in
kg/kWh by the annual electricity generation for the power plant.
See Appendix 4
Data will be checked on an annual basis with NTDC to ensure that changes or
additions to the fuel consumption used in the tariff determinations by NEPRA in
case of thermal power plants are taken into consideration. Based on updated
information, the data will then be converted to mass unit by multiplying the data
by the annual electricity generation of the power plant
Dispatch data OM: annually for the year y in which the project activity is
displacing grid electricity.
NTDC uses the fuel consumption data to calculate the fuel charge on the
electricity bill of the consumers. Therefore, the values they use follow the highest
standards.
Monitoring frequency
QA/QC procedures
Source of data
Value(s) applied
Measurement methods
and procedures
Monitoring frequency
QA/QC procedures
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Purpose of data
Calculation of baseline emissions
Additional comment
No independent data is available from power generation plants
Data / Parameter
EGn,y and EGn,h
Unit
Description
MWh
Net electricity generated by power plant / unit n in year y or hour h
NTDC half hourly electricity generation data for all grid connected power plants
in Pakistan that are based on dispatch data from the National Power Control
Centre and forwarded to NTDC on a daily basis.
See Appendix 4 and GEF calculation sheet for hourly data
Data are obtained directly from NTDC which is the utility in charge of electricity
distribution in the country.
Source of data
Value(s) applied
Measurement methods
and procedures
Monitoring frequency
The data will be collected from NTDC on a half-yearly basis and aggregated on an
annual basis.
Purpose of data
Firstly, dispatch data as provided by NTDC will be analysed for quality and any
obvious errors (e.g. manual input mistakes) resolved. Secondly dispatch data will
be compared on a yearly basis with the net generation figures provided in Energy
Year Book / State of Industry Report.
Calculation of baseline emissions
Additional comment
-
QA/QC procedures
B.7.2. Sampling plan
No data and parameters monitored are to be determined by a sampling approach.
B.7.3. Other elements of monitoring plan
The ‘quantity of net electricity generation EGfacility,ysupplied by the project plant/unit to the grid in year y
and the listed parameters to calculate the grid emission factor will require monitoring. This is because the
grid emission factor will be calculated using the Dispatch Data Analysis OM approach. Therefore annual
recalculation of the emission factor during the credit period will be required.
Operational and management structure
Overall authority and responsibility for monitoring will rest with HAWA Energy. HAWA Energy will be
responsible for technical aspects related to monitoring such as:






Training of personnel
Calibration and maintenance of equipment
Physical reading and day-to-day handling
Long-term storage of metered data for the reporting and verification process
Data collection from NTDC and the IPCC Guidelines on National Greenhouse Gas Inventories
Quality Control and Quality assurance measures
Monitoring training sessions will be carried out by the carbon consultant and the EPC consultant in order to
ensure compliance with the relevant monitoring requirements under the overall responsibility of HAWA
Energy. In addition, HAWA Energy will be responsible for collection and management of data required for
monitoring from the following entities:




National Transmission and Despatch Company (NTDC)
Hydrocarbon Development Institute of Pakistan (HDIP)
National Electric Power Regulatory Authority (NEPRA)
The IPCC Guidelines on National Greenhouse Gas Inventories
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Training
A training session for HAWA Energy will be conducted by the carbon consultant before the project is
implemented in order to ensure a common understanding of the CDM monitoring procedures and
requirements. The training will include the following contents:







CDM project cycle and the significance of monitoring
Management structure and work scope
Components of the monitoring plan
QA/QC procedures
Monitoring report template
Preparation for verification
Questions and answers
Furthermore a training session for monitoring staff will be conducted before the start of operation by the
EPC consultant regarding the operating, metering, calibration and maintenance practices.
B.8.
Date of completion of application of methodology and standardized baseline and contact
information of responsible persons/ entities
Data management provisions
A centralized database will be used to store and archive the data from the different sources. Emission
reduction data monitoring and management procedures will be put in place prior to the starting date of the
crediting period. All data collected as such will be archived electronically and be kept at least for two years
after the end of the last crediting period.
Position of the electricity meters
A main and a backup electricity metering system will be installed at project site in pursuant to EPA to be
signed between Central Power Purchase Agency (CPPA)/ National Transmission and Despatch Company
(NTDC) and HAWA Energy:
Data collection and recording, management and archiving, Quality assurance and Quality control
In order to monitor the grid emission factor HAWA Energy will collect the following data from National
Transmission and Despatch Company (NTDC):
Description
Data recording
Data collection
Data management and
archiving
Quality Assurance and
Quality Control
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FCi,n,y: Amount of fossil fuel type iconsumed by power plant / unit n (or in the
project electricity system in case of FC) in year y.
In terms of fossil fuel consumption, NTDC calculates fossil fuel consumption in
kg/kWh. NTDC uses this data to calculate the fuel charge for the electricity bill.
Fuel consumption data will be collected on an annual basis by HAWA Energy.
Based on the fuel consumption in kg/kWh provided by NTDC, HAWA Energy will
calculate the fuel consumption in kg by multiplying for each power plant the
value in kg/kWh by the annual electricity generation.
Fossil fuel consumption data will be checked on an annual basis with NTDC to
ensure that changes or additions to the fuel consumption are taken into
consideration. Based on updated information, the data will then be converted to
mass unit by multiplying the data by the annual electricity generation of the
power plant (for monitoring and quality assurance information for annual
electricity generation data, see parameter EGm,y, EGn,h).
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Description
Data recording
Data collection
Data management and
archiving
EGn,yandEGn,h: Net electricity generated and delivered to the grid by power plant
/ unit n (or in the project electricity system in case of EG) in year y or hour h
In terms of net electricity generated, NTDC keeps half hourly records of the
amount of electricity that is supplied by the different power plants that are
connected to the national grid. These records are then entered into a centralized
database. NTDC receives the data on a daily basis from the National Power
Control Centre.
Electricity generation data will be collected by HAWA Energy on a half-yearly
basis and aggregated on a yearly basis.
Based on the half hourly dispatch data, HAWA Energy will calculate hourly
dispatch data and store the data in a centralized database.
For power plant net energy generation, dispatch data as provided by NTDC will
be analysed for quality and any obvious errors (e.g. manual input mistakes)
resolved. Secondly dispatch data will be compared on a yearly basis with the net
generation figures provided in HDIP in Energy Year Book. Any significant
discrepancies will be brought to the attention of NTDC and in the case of nonresolution, the more conservative of the two values will be used. A more detailed
description for the QA/QC procedures on electricity generation data is given
below:
 Step 1: If data is missing the following procedure will be followed:
o In the case of a renewable energy plant:
 Missing data for a particular hour in a particular month will be replaced
by the average of the electricity generation data for that same hour in
that particular month
o In the case of fossil fuel based plant:
 The electricity generation for which data is missing will be set at zero
 Step 2: Check data for errors and extreme values. Delete (i.e. set equal to
zero) errors and extreme values in the electricity generation data.
 Step 3: Calculate annual electricity generation per power plant and compare
value with the annual electricity generation as is officially reported by NTDC
and recorded in Energy Year Book. The following maximum % difference
between the official NTDC values and the calculate values will be allowed:
Quality Assurance and
Quality Control
< 50,000 MWh
Maximum
allowable
difference
between NTDC official values and
calculated values
±7.5%
50,000 – 250,000 MWh
±5.0%
250,000 – 500,000 MWh
±2.5%
Annual Electricity
Power Plant (MWh)
generation
by
> 500,000 MWh
±1.5%
 Step 4: If the calculated values exceed the maximum allowable difference
with the official NTDC values, the following steps will be taken:
a. If it concerns a renewable energy plant, then check whether the subtotal
for the renewable energy power plants of the same type (e.g. subtotal for
all hydro power plants) also exceeds the maximum allowable difference.
b. If the subtotal does not exceed the maximum allowable difference, then
the error is disregarded.
c. If the subtotal also exceeds the maximum allowable difference, or in case a
fossil fuel fired power plant exceeds the maximum allowable difference,
try to identify the source of the difference and correct it if possible.
d. If the source of the difference cannot be identified or cannot be corrected
than the following procedure will be followed in order to ensure
conservativeness: In the case of a renewable energy power plant, the
highest value between the NTDC official value and the calculated value will
be used. In the case of a fossil fuel based power plant, the lowest value
between the NTDC official value and the calculated value will be used.
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Description
Data recording
Data collection
Data management and
archiving
Quality Assurance and
Quality Control
Description
Merit Order
The merit order is determined by NTDC on a monthly basis based on the cost of
electricity from the different power plants in the previous months.
Merit order data will be collected by HAWA Energy on a yearly basis.
Data regarding the merit order will be organized annually and stored in a
centralized database.
Data regarding the merit order will be checked in terms of logic (cheap sources
should rank higher in the merit order) and consistency. If merit order data are
missing for a particular month, data from the previous month will be used.
Information on power plants (including
commissioning and fuel type used)
installed
capacity,
year
of
Data collection
HAWA Energy will collect and (including installed capacity, year of
commissioning and fuel type used) from NTDC on an annual basis. The main
source of this information will be NTDC compile information on power plants
through annual Energy Year Books published by Hydrocarbon Development
Institute of Pakistan (HDIP), Government of Pakistan and State of Industry
Reports published by NEPRA, Government of Pakistan.
Data management and
archiving
Information on power plants will be organized annually and stored in a
centralized database.
Quality Assurance and
Quality Control
Information regarding power plants will be cross-checked with other available
information sources, including information sources from PPIB, AEDB and the
Ministry of Water & Power.
In order to monitor the grid emission factor, HAWA Energy will collect NCVi,y and EFCO2,i,yas IPCC default
values at the lower limit of the uncertainty at a 95% confidence interval as provided in the latest available
version of IPCC Guidelines on National GHG Inventories
Description
NCVi,y: Net calorific value (energy content) of fossil fuel type iin year y
Data collection
HAWA Energy will collect and verify the data with the latest version of the IPCC
guidelines on an annual basis.
Data management and
archiving
HAWA Energy will store the data from IPCC in a centralized database
Quality Assurance and
Quality Control
Possible updates and revisions to relevant IPCC reports and databases will be
reviewed. The data obtained from the IPCC will be crosschecked with other
reputable sources, including reliable national data if such becomes available. In
the case of inconsistencies, the more conservative of two values will be used.
Description
Data collection
EFCO2,i,y:Emission factor of fossil fuel type iin year y
HAWA Energy will collect and verify the data with the latest version of the IPCC
guidelines on an annual basis.
Data management and
archiving
HAWA Energy will store the data from IPCC in a centralized database
Quality Assurance and
Quality Control
Possible updates and revisions to relevant IPCC reports and databases will be
reviewed. The data obtained from the IPCC will be crosschecked with other
reputable sources, including reliable national data if such becomes available. In
the case of inconsistencies, the more conservative of two values will be used.
In order to monitor the annual net electricity generation supplied to the grid by the project activity, the
following procedures will be followed by HAWA Energy
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Description
Data recording
Data collection
Data management and
archiving
Quality Assurance and
Quality Control
SECTION C.
C.1.
EGfacility,y and EGPJ,h: Quantity of net electricity generation supplied by the project
plant/unit to the grid in year y and hour h
The project proponents will install a Main Metering System and Back-Up
Metering System on-site. Both Main and Back-Up Metering System will be
jointly owned and operated by HAWA Energy and NTDC. Supply, installation,
testing and commissioning of the Metering Systems will be carried out by
HAWA Energy with the assistance of NTDC in line with the EPA. HAWA Energy
and NTDC will also adopt and implement the procedures and arrangements for
reading, testing, adjusting and re-calibrating the Metering Systems in
accordance with the specifications of the National Grid Code or other relevant
national standards, as the case may be. The net quantity of electricity generated
is metered on site using the main metering system (SCADA controls and
communication) and quantified in generation data and power export invoices to
NTDC. HAWA Energy shall install a data recorder and shall make a continuous
recording of the Net Electrical Output. Such Net Electrical Output shall be
recorded on appropriate magnetic media or equivalent. The quantity of
electricity supplied to the grid will be measured continuously and recorded
monthly. The basic measurement period shall be carried out in line with the
EPA. The metering shall register per measurement period the following data:
per kWh and kVArh meter the delivered energy and reactive power and the
metering period. The data shall be stored in long-term data storage. All data
shall be transferred to the meter data buffer and to the SCADA systems of both
NTDC and HAWA Energy.
The Metering System shall be read monthly on the last day of each month (or
such other day as may be agreed upon by the parties) for the purpose of
determining the Net Electrical Output of the Plant since the preceding reading.
HAWA Energy shall read the Metering System by reading the log in the SCADA
system and taking the kWh meter position on the first day of the calendar
month at 0:00 mid-night. NTDC shall verify the same.
Information on power plant will be organized monthly and summarized annually
and stored in a centralized database managed by HAWA Energy.
The main metering requirements according to the EPA and the Grid Code will be
met. The equipment will also comply with international standards. Any
programmable settings available within a metering installation, data logger or
any peripheral device, which may affect the resolution of displayed or stored
data, shall meet the relevant requirements as per EPA. The method of
calibration and frequency of tests shall be agreed between HAWA Energy and
NTDC based on requirements outlined in the EPA and the Grid Code. The meters
will have a fixed seal not to be broken by the project proponent. Reconciliation
of data with backup metering system will be done as needed. This data will be
double-checked with receipt of sales/invoices from NTDC. In case of any
difference, the most conservative (i.e. lower) value of both the invoice and the
meter reading value will be used for the purpose of calculating the emission
reductions. Photographic facilities will also record the metered data as part of
monthly onsite verification procedures. In order to ensure conservativeness,
Non-Project Missed Volume of Energy (electrical energy not delivered to the
grid due to NTDC system interruption) will not be included in emission
reduction calculations.
Duration and crediting period
Duration of project activity
C.1.1. Start date of project activity
20thApril, 2016
According to version 08 of the CDM glossary of terms, the start date of a project activity is defined as:
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“In the context of a CDM project activity or PoA, the earliest date at which either the
implementation or construction or real action of a CDM project activity or PoA begins.”
The project participant is expected to sign EPC contract on 20/04/2016. This marks the start date of the
project activity since the project participant makes a commitment toward implementing the project.
C.1.2. Expected operational lifetime of project activity
20 years (240 months)
C.2.
Crediting period of project activity
C.2.1. Type of crediting period
Renewable crediting period (first)
C.2.2. Start date of crediting period
01/12/2017
C.2.3. Length of crediting period
7 years (84 months)
SECTION D.
Environmental impacts
D.1.
Analysis of environmental impacts
In line with the Pakistan Environmental Protection Act 1997 and Guidelines for Environmental Assessment
for Wind Power Projects, the project activity has carried out an Initial Environmental Examination (IEE).
The most significant environmental impacts associated with the proposed project include:
 Visual impacts on the natural scenic resources of the region;
 Local site-specific impacts as a result of the construction and operational phases of the project;
The IEE study has been used to predict the environmental impacts and propose mitigation measures.
Overall, the proposed wind energy facility is expected to have a low-medium to low impact on ecology
within the project area prior to mitigation. This could be reduced to very-low after mitigation. The primary
negative impacts are the result of both direct and indirect factors. Direct impacts include loss of natural
vegetation in areas that will be disturbed by heavy construction machinery, laydown areas, etc.
The impacts on surface water quality are expected to be low without mitigation and can be reduced to
very-low with mitigation. The primary negative impacts are the result of contamination of water bodies
during the construction phase due to silt laden water run-off and hydrocarbon contamination arising from
construction plant and equipment.
The proposed wind energy facility is expected to have a low impact on the geological environment and
these impacts can be largely mitigated to a resultant very-low significance if appropriate measures are
diligently applied. The planning of construction activities should take consideration of areas which are
potentially sensitive to erosion such as drainage lines. No insurmountable geotechnical problems were
identified in the geology and soils study and the site appears to be suitable for the development as
planned.
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The primary concern for the proposed wind energy facility on avifauna is the collision of birds with the wind
turbines. The impact on avifauna is potentially of medium-high significance but can be reduced to very-low
with the implementation of mitigation measures. Bird monitoring will continue at Jhimpir until December
2015.
The noise impact on the surrounding areas is of low-medium significance. The potential impact on sensitive
receptors within the proposed wind energy facility is potentially low depending on the final turbine
placement. It is important that the results of the noise predictions be considered during the final design of
the wind energy facility to reduce potential impacts to a more acceptable low significance.
The placement of the wind energy facility will have a visual impact on the natural scenic resources and rural
character of the project area Jhimpir and county in general. Potential visual impacts are of medium-high to
low-medium significance. The visual impact of the core facility (mainly the wind turbines) is not readily
mitigated due to the size of the structures in the landscape and the remoteness of the site from large
human settlements.
The placement of each wind turbine currently shows that the potential impacts of shadow flicker are of low
significance without implementation of any mitigation measures and of very-low significance after
implementing mitigation measures. Since there are no dwellings at or near the project site, none of the
households would be affected by the conservative shadow flicker assessment. The overall evaluation of the
proposed wind energy project from an environmental perspective indicates that there are a number of
issues that require mitigation. The mitigation measures and the EMP included in this report are essential
risk mitigation components that should be implemented during the preconstruction, construction and
operational phases respectively
The significance of the majority of identified negative impacts can generally be reduced by implementing
the recommended mitigation measures. Subsequently it is recommended that:







All mitigation measures stated in this IEE Study will be implemented.
The Environment Management Plan (EMP) should form part of the agreement with the contractors
appointed to build and maintain the proposed wind energy facility, and will be used to ensure
compliance with environmental specifications and management measures. Compliance with the
EMP throughout the life cycle of the project is considered to be important in achieving the
appropriate environmental management standards as detailed for this project.
As far as practical, wind turbines and associated lay down areas and access roads which could
potentially impact on sensitive receptors should be shifted to avoid areas of high sensitivities.
Where this is not possible, alternative mitigation measures detailed in this report should be
implemented;
Disturbed areas should be rehabilitated as quickly as possible and an on-going monitoring program
should be considered to detect and quantify any alien species;
During the construction phase, unnecessary disturbance to habitats should be strictly controlled
and the footprint of the impact should be kept to a minimum;
A comprehensive storm water management plan should be compiled for the sub-station footprints
prior to construction;
Applications for all relevant and required permits required to be obtained by HAWA Energy (Pvt.)
Ltd. must be submitted to the relevant lead agencies.
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D.2.
Environmental impact assessment
An IEE study has been carried out in order to evaluate the potential environmental and social impacts
associated with all phases of the project (construction, operation and decommissioning). The conclusions
and recommendations of this IEE study are the result of the assessment of identified impacts by the Firm of
experts and their specialists including the process of public stakeholder consultation. The public
stakeholder consultation process has been extensive and every effort was made to include representatives
of all stakeholders in the study area.
The most significant environmental impacts associated with the proposed project include:


Visual impacts on the natural scenic resources of the region;
Local site-specific impacts as a result of the construction and operational phases of the project;
The significance of the majority of identified negative impacts can generally be reduced by implementing
the recommended mitigation measures
The EIA NOC was granted by the Sindh Environmental Protection Agency on the (17thDec 2012), (NOC)
number [2012/12/17/IEE/23].
SECTION E.
Local stakeholder consultation
E.1.
Solicitation of comments from local stakeholders
The CDM Glossary of terms (version 08) defines stakeholders as “the public, including individuals, groups or
communities affected, or likely to be affected, by the proposed CDM project activity or PoA, or actions
leading to the implementation of such an activity”.
In the context of the proposed Hawa Wind Power Project, the main stakeholders of the project are the
communities and groups living in the vicinity of the area where the project will be implemented and the
landowners of the project activity. Additional relevant stakeholders are mainly entities engaged in the
Pakistani electricity sector and environmental NGOs related to the project activity. A CDM stakeholder
consultation meeting was carried out on April 27, 2016 (through an advertisement in Newspapers namely:
Nawa e Waqt, The Nation & Local Newspaper Awami Awaz) at the Project Site in Jhimpir. The purpose of
the meeting was to invite the local population to register their comments / suggestions / observations /
desires regarding the project. Around 20 persons from the local areas attended this meeting. The meeting
was conducted in Urdu and local Sindhi Language.
All the local stakeholders were present on the site. First of all the team introduced and the purpose of the
visit were explained to all the stakeholders. The Malik of the village was the main respondent from all the
villagers’ side. The main concerns of the community regarding the Wind power project were:1.
2.
3.
4.
The land to be used by the Hawa Energy Pakistan Private Limited should be compensated at a good
property rate to the owners.
Employment of the local people of the community must be ensured.
Arrangement of clean drinking water to the community.
Development of roads infrastructure
In the meeting stakeholders registered their comments and observations through emails, telephones and
faxes. Moreover, Ministry of Climate Change, Ministry of Environment, and Alternate Energy Development
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Board were contacted for their inputs regarding the project. In response most of the stakeholders
appreciated the effort of utilizing clean source of energy to generate electricity and help addressing the
countries issues like energy shortage, energy security, and provision of electricity to remote areas, poverty
alleviation and remote communities uplift.
Local community also highlighted the efforts of Hawa Energy in provision medical and educational facility to
the locals. Moreover, the project company have also hired local men as security guards at project site. The
project company have also committed to local that they will provide labour opportunities to them during
project implementation phase
For the proposed wind energy facility, public/stakeholder consultation has been an on-going process. Apart
from the CDM stakeholder consultations, the project activity has carried out and will carry out a number of
other stakeholder consultations with local leaders, community representatives and other relevant
stakeholders. These consultations have taken place/will take place as part of the project preparation. Hawa
Energy has from the onset had engagement sessions with the Ministry of Water & Power, land owners in
the project area, Jhimpir community among others. The engagement sessions have been fruitful in
explaining the proposed project to the communities residing in Jhimpir and getting their approval for
signing up land leases for the wind energy facility. Public meetings with the provincial administration and
local land owners were held throughout the detailed environmental assessment phase. Additionally focus
group discussions and key informant interviews were held over a six month period. The public/stakeholder
consultation process will continue into the pre-construction, construction and operational phases of the
project respectively.
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E.2.
Summary of comments received
During the stakeholder consultations comments on the project were made and issues were raised. The
following provides an overview of the most important topics that were discussed:
E.2.1 Benefits caused by the project activity
From a general point of view, stakeholders of Hawa Wind Power Project rate the impacts of the project as
being positive and are committed to the project on broad-based basis. The economic impacts are rated
positively especially because stakeholders see a positive impact on the economic activity in the project
area, on long-term cost of energy, on the possibility to attract foreign investment and possibility of transfer
of modern technologies as a result of the implementation of the project activity.
The stakeholders are also aware that the project will contribute in a positive way to Pakistan’s electricity
security which will have positive effects for domestic industry and economy in general. Stakeholders are
also aware that the project will have a positive effect on the mitigation of climate change.
E.2.2 Engagement of the local community and benefit sharing:
A focus of interest during the consultation meeting was the engagement of the local community in the
project development. Furthermore the question was raised how the Jhimpir community will benefit from
the additional carbon credit revenue.
Relocation of communities and access to the area
Stakeholders were interested to know if the houses of the local community will be relocated as a result of
the project activity and if they will still have access to their land.
Environmental impacts
Stakeholders mentioned that the project might have negative environmental impacts such as noise, visual
impacts, water quality and the likelihood interfering with migratory bird path because the proposed project
area is famous for its diversity of birds.
Local employment opportunities
Stakeholders were interested if the project will offer local employment opportunities.
Role of Renewable Stars (Pvt.) Ltd.
Stakeholders were also interested to know if Renewable Stars (Pvt.) Ltd. as a CDM consultant will also
benefit from the additional carbon credit revenue and who will receive and control the carbon credits.
E.3.
Report on consideration of comments received
SECTION F.
Approval and authorization
The Letter of Approval issued by the host Party, Islamic Republic of Pakistan, for the project activity is not
available at the time of submitting this PDD to the validating DOE.
Contact information of project participants and responsible persons/ entities
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Project participant and/or
responsible person/ entity
Project participant
Responsible person/ entity for application of the
selected methodology (ies) and, where applicable, the
selected standardized baselines to the project activity
Organization name
Renewable Stars (Pvt.) Ltd.
Street/P.O. Box
House No. 10, Street No. 135, G-13/4
Building
-
City
Islamabad
State/Region
Islamabad
Postcode
44000
Country
Pakistan
Telephone
0092 51 2301183
Fax
009251 8358592
E-mail
[email protected]
Website
www.renewablestars.com
Contact person
Imran Yousuf
Title
Director
Salutation
Mr.
Last name
Yousuf
Middle name
-
First name
Imran
Department
-
Mobile
0092-345-5063979
Direct fax
-
Direct tel.
-
Personal e-mail
[email protected]
Organization name
Street/P.O. Box
Building
City
State/Region
Postcode
Country
Telephone
Fax
E-mail
Website
Contact person
Title
Salutation
Last name
Middle name
First name
Department
Mobile
Direct fax
Direct tel.
Personal e-mail
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HAWA Energy (Pvt.) Ltd.
68, Nazimuddin Road, Sector F-8/4, Islamabad
Islamabad
Islamabad
Pakistan
+9251 2600205, +92300 8544516
[email protected]
http://www.hawa-energy.com
Mr Bruno Bucari
CEO
Mr.
Bucari
Bruno
Commercial
-
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Appendix 1.
Affirmation regarding public funding
No public funding is involved in the project activity
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Appendix 2.
Applicability of methodology and standardized baseline
No additional information
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Appendix 3.
Further background information on ex ante calculation
of emission reductions
To calculate the emission factor for the Pakistan electricity system in line with the “Tool to calculate the
emission factor for an electricity system (version 5)”, the operating margin (OM) and build margin (BM)
emission factors are based on the following parameters and values:
Fossil Fuel Power Plants included in OM
Power Plant Name
Date of Commissioning
Technology
Fuel
Installed Capacity
WAPDA
GTPS Shahdra
Aug-69
Engines
NG/HSD
44
MW
SPS Faisalabad
Nov-67
Engines
NG/FO
132
MW
GTPS Faisalabad
Nov-75
GT
NG/HSD
244
MW
NGPS Multan
Nov-63
Engines
NG/FO
260
MW
TPS M.Garh
Dec-95
Engines
NG/FO
1130
MW
TPS Guddu (1-4)
Feb-85
GT
NG/FO
1655
MW
TPS Guddu (5-13)
GTPS Kotri
FBC Lakhra
TPS Jamshoro
TPS Quetta
TPS Pasni
GTPS Panjgur
Mar-94
1981
1996
Jan-91
Nov-84
GT
GT
FB
Engines
GT
NG/HSD
NG
Coal
FO/NG
FO/NG
1015
174
150
850
35
17
39
MW
MW
MW
MW
MW
MW
MW
IPPs
AES Lalpir, M.Garh
AES Pak Gen, M.Garh
Altern Energy
Attock Gen
Atlas Power
Engro Energy Ltd.
Fauji, Kabirwala
Foundation Power
Habibullah
Halmore Power
Hubco, Hub
Hub Power Narowal
Japan Power
KAPCO, KotAddu
Kohinoor Energy, Lahore
Liberty Power Tech
NishatChunian Power
Nishat Power
Orient Power
06.11.1997
01.02.1998
06.06.2001
17.03.2009
18.12.2009
27.03.2010
21.10.1999
16.05.2011
11.09.1999
16.06.2011
31.03.1997
22.04.2011
14.03.2000
27.06.1996
20.06.1997
13.01.2011
21.07.2010
09.06.2010
24.05.2010
Steam turbines
Steam turbines
Gas engine
Engines
CCGT
CCGT
CCGT
CCGT
CCGT
CCGT
Steam turbines
Engines
Engines
CC
Engines
Steam turbines
Reciparocating Engines
CC
CC
FO
FO
Flaregas
HSD
Gas+HSD
Gas+HSD
Gas+HSD
Gas+HSD
Gas
Gas+HSD
FO
HSD
FO
FO
FO
FO
FO
FO
FO
362
365
31
165
214
217
157
185
140
225
1292
220
135
1638
131
202
200
200
229
MW
MW
MW
MW
MW
MW
MW
MW
MW
MW
MW
MW
MW
MW
MW
MW
MW
MW
MW
Rousch Power
11.12.1999
CC
FO
450
MW
Saba Power
31.12.1999
Steam turbines
FO
134
MW
Saif Power
27.04.2010
CCGT
Gas
229
MW
Southern Electric
10.03.1999
Engines
FO
586
MW
Sapphire Electric
04.10.2010
CC
FO
225
MW
TNB Liberty Power
10.09.2001
CCGT
Gas
235
MW
Uch Power
18.10.2000
CCGT
Low-btu Gas
586
MW
Uch II Power
25-04-2014
CCGT
Gas+HSD
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KESC
TPS Bin Qasim II
TPS Korangi
GTPS Korangi Town
GTPS SITE
TPS Bin Qasim
Gul Ahmed
Tapal
Jan-12
Nov-1965
ST
ST
GT
GT
ST
DG
DG
GAS+RFO
GAS
GAS+RFO
560
316
80
100
1260
136
126
MW
MW
MW
MW
MW
MW
MW
For all hydro, geothermal, biomass and wind power plants EFel,n,y is 0.
Power plants included in the build margin (BM) emission factor:
Table: Power Plants included in the build margin (BM)
Sr. No.
Power Plant Name
Date of
Commissioning
Technology
Fuel
Installed Capacity
CCGT
GAS+HSD
404 MW
1.
Uch II Power
2.
Jinnah
Jan-13
-
Hydel
96
MW
3.
AKHP
Jul-12
-
Hydel
121
MW
4.
TPS Bin Qasim II
Jan-12
ST
Gas+RFO
560
MW
5.
Hub Power Narowal
22.04.2011
Engines
HSD
220
MW
6.
Liberty Power Tech
13.01.2011
Steam turbines
FO
202
MW
7.
KKHP
11.08.2010
Hydel
72
MW
8.
NishatChunian Power
21.07.2010
Reciparocating
Engines
FO
200
MW
9.
Nishat Power
09.06.2010
CC
FO
200
MW
10.
Orient Power
24.05.2010
CC
FO
229
MW
11.
Saif Power
27.04.2010
CCGT
Gas
229
MW
12.
Engro Energy Ltd.
27.03.2010
CCGT
Gas+HSD
217
MW
13.
Ghazi Barotha
01.07.2003
RoR
Hydel
1450
MW
14.
TNB Liberty Power
10.09.2001
CCGT
Gas
235
MW
15.
Altern Energy
06.06.2001
Gas engine
Flaregas
31
MW
16.
Chashma
01.06.2001
184
MW
17.
Uch Power
18.10.2000
CCGT
Hydel
Low-btu
Gas
586
MW
For all hydro, geothermal, biomass and wind power plants EFel,m,y is 0.
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Appendix 4.
Further background information on monitoring plan
No additional information
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Appendix 5.
Summary of post registration changes
N/A
-----
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Document information
Version
Date
Description
06.0
9 March 2015
Revisions to:
05.0
25 June 2014

Include provisions related to statement on erroneous inclusion of
a CPA;

Include provisions related to delayed submission of a monitoring
plan;

Provisions related to local stakeholder consultation;

Provisions related to the Host Party;

Editorial improvement.
Revisions to:

Include the Attachment: Instructions for filling out the project
design document form for CDM project activities (these
instructions supersede the "Guidelines for completing the project
design document form" (Version 01.0));

Include provisions related to standardized baselines;

Add contact information on a responsible person(s)/ entity(ies) for
the application of the methodology (ies) to the project activity in
B.7.4 and Appendix 1;

Change the reference number from F-CDM-PDD to CDM-PDDFORM;

Editorial improvement.
04.1
11 April 2012
Editorial revision to change version 02 line in history box from Annex 06 to
Annex 06b
04.0
13 March 2012
Revision required to ensure consistency with the “Guidelines for
completing the project design document form for CDM project activities”
(EB 66, Annex 8).
03.0
26 July 2006
EB 25, Annex 15
02.0
14 June 2004
EB 14, Annex 06b
01.0
03 August 2002
EB 05, Paragraph 12
Initial adoption.
Decision Class: Regulatory
Document Type: Form
Business Function: Registration
Keywords: project activities, project design document
Version 06.0
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