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1
Experiences withElectricity
Tariff Reforms
ERRA Tariff / Pricing Committee meeting October 19, 2016
Bratislava, Slovakia
Presented by:
Muhammad SafdarNEPRA, Pakistan
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Experiences with electricity Tariff Reforms
• Introduction of NEPRA
• Organogram
• Mandate & Functions
• Restructuring of WAPDA
• Experiences of Tariff w.r.t Generation,
Transmission & Distribution Sector
• Q/A
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Organogram
Registrar
Vice Chairman by rotation on yearly basis
MEMBERBALOCHISTAN
MEMBERPUNJAB
CHAIRMAN
MEMBERKhyber
Pakhtunkhwa
MEMBERSINDH
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Mandate
• To develop and pursue a Regulatory Framework that
ensures provision of safe, reliable, efficient and
affordable electric power to the electricity consumers
of Pakistan.
• Facilitate transition from a protected monopoly
service structure to a competitive environment.
• Maintain balance between the interests of the
consumers and investors.
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Main Functional Areas
• Licensing
• Tariff
• Performance Standards
• Consumer Affairs
• Monitoring and Enforcement
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Extra High Voltage System of Pakistan
MARDANWARSAK
BANNU
DAUDKHEL
BURHANNEW RAWAT
I.S.P.R
MANGLA
TARBELA
GAKHAR
SAHOWALA
K.S.KAKU
RAVI
JAPAN
KELN.ABAD
SABA
YOUSAF WALA
VEHARI
KAPCO
ROUSCH
UCH
AES
N.G.P.SM.GARH
GUDDU
LIBERTY
DADU
HALARD
LAKHRA
JAMSHORO
KOTRI
HUBCO
KDA-33(KESC)
500 kV Grid Station
220 kV Grid Station
500/220 kV Grid Station
Hydel Power Station
Thermal Power Station
IPPs at 220, 500 kV
IPPs at 132 kV
500 kV T/LINE
220 kV T/LINE
(240)
(3408)
(1000)
(107)
(120)
(195)
(1350)
(310)
CHEP
(184)
(355)
(1348)
(695)
HCPC(126)
(548)
(1655)
(212)
(150)
(850)
(174)(1200)
GAZI BAROTHA
(1450)
CHASNUPPGATTI
BUND RD:
M.GARHGUDDU
JAMSHORO
TAPAL
G.AHMAD
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Power Sector Players
KANUPP
PUBLIC SECTOR PRIVATE SECTOR
NEPRAMinistry of
Water & Power
Pakistan Atomic
Energy CommissionK -ELEC IPPs SPPs/CPPs
CHASHNUPPPPIBPEPCOWAPDA(HYDRO)
AEDB
GENCOs
NTDC/CPPA
DISCOs
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Restructuring of WAPDA
TRANSMISSION
N T D C
1
POWER WING
GENERATION DISTRIBUTION
Grid Station / Trans. Lines
Operation & Maintenance
Thermal Power
Stations
GENCOs
5
DISCOs
12
Area Electricity Boards
TRANSFORMING THESE ORGANIZATIONAL COMPONENTS
INTO INDEPENDENT CORPORATISED ENTITIES
One Hydel
Four Thermal
CPPA-G
IPPs
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Installed Generation Capacity by Type
SourceInstalled Capacity
(MW)%
Energy Generation(GWh)
%
Thermal 16,664 67.13 69,886 64.34
Hydel 7,116 28.67 32,979 30.36
Nuclear 787 3.17 5,349 4.92
Wind 106 0.43 300 0.28
Coal 150 0.60 102 0.09
TOTAL 24,823 100.00 108,616 100.00
Thermal(64.34%)
Hydel(30.36%)
Nuclear(4.92%)
Wind(0.28%)
Coal(0.09%)
Energy Generation (GWh)
Thermal(67.13%)
Hydel(28.67%)
Nuclear(3.17%) Wind
(0.43%)
Coal(0.60%)
Installed Capacity (MW)
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Chain of Cost Components
Fuel Suppliers Refineries/ Gas Cos.
Public Sector GENCOs Thermal / Hydel / Nuclear
Private SectorIPPs
Transmission / CPPA-G
IESCO LESCO GEPCO MEPCO FESCO PESCO HESCO QESCO KESC
CONSUMERSResidential/ Commercial/ Industrial/ Agriculture/ Others
Gen
erat
ion
Co
stT
ran
s. C
ost
&L
oss
Ad
j.D
ist.
Co
st &
L
oss
Ad
j.
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Experiences with electricity Tariff Reforms
Pricing Mechanism Stakeholders Involvement Stipulated Timeline
Upfront Tariff Modeunder NEPRA UpfrontTariff Regulations, 2011
(Via Suo Moto Proceedingsor any GOP agency file arequest with NEPRA)
Stakeholders are invited totake part in an extensiveconsultative process, whenthe upfront tariff for eachtechnology is beingdetermined.
The Authority shalldecide within 10working days of thefiling of a completeapplication forupfront tariff.
Cost Plus Mode underNEPRA Tariff Rules – 1998
(Any person / party mayfile a petition along withdocumentary evidence toNEPRA)
Stakeholders are invited toparticipate in the proceedingsthrough public noticespublished in national dailies,in both Urdu and Englishlanguages. Individual lettersare also sent to stakeholders.
The Authority shalldecides a petitionwithin 4 months ofadmission, whichmay be extended foranother 4 months.
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Experiences with electricity Tariff Reforms
Energy Charge
- Fuel
- Variable O&M
Capacity Charge
- Fixed O&M
- Local
- Foreign
- Return on Equity
- Return on Equity during Construction
- Insurance
- Debt Repayment
- Principal Amount
- Interest Payment
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Experiences with electricity Tariff Reforms
14
Demand Supply Situation
Financial
Year ending
30th June
Planned
Generation
Capability as
per NTDC
(MW)
NTDC
Projected
Demand
Growth Rate
(%)
NTDC's
Projected
Demand
during Peak
Hours (MW)
Surplus/
(Deficit)
(MW)
2016 17,551 5.98 22,457
-4,906
201720,641 6.05
23,816-3,175
201825,077 5.56
25,140-63
201929,171 5.17
26,4392,732
202031,216 4.86
27,7253,491
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Upfront Tariff for Different Technologies
TechnologyCost/kWh(US Cents)
Cost/MW(Million
US$)
Coal Foreign Financing 8.02 – 8.64 1.53 – 1.64
Thar Coal Foreign Financing 7.99 – 8.52 1.35 – 1.51
WindForeignFinancing
10.45 2.26
Solar (Foreign Financing)
North Region 11.36 – 11.531.50
South Region 10.73 – 10.89
Bagasse (Local Financing) 10.62 1.00
Small Hydel (local financing) 10.06 – 12.78 2.8 – 4.2
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Pricing Framework Small Hydel
Incentives
IRR 20%
ROE 27.4%
Spread over LIBOR 4.5%
Spread over KIBOR 3.5%
Tariff Control Period 30 years
Insurance 1.35% of EPC
O&M CostsHigh Head = US Cents 0.9648/ kWh (50%)Low Head = US Cents 1.0389/ kWh (65%)
Timeline
Opt for Tariff One year from the date of determination
Financial Close 18 months from date of acceptance of upfront tariff
Construction Period 36 months from financial close
Coverage Inflation Risk, Exchange Rate Risk, LIBOR/ KIBOR change, Insurance etc
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Pricing Framework Wind
Tariffsx1
Project Cost
(USD Millionper MW)
EPC Cost (USD Million
per MW)
Non - EPC Cost
(USD Million per
MW)
Financing Cost
(USD Million per MW)
Capacity Factor
(%)
Levelized Tariff
(US Cents/kWh)
ProjectsAwarded
Tariff
2011 2.60 2.31 0.11 0.18 31% 14.66 100
2013 2.46 2.22 0.10 0.16 31% 13.52 1025
2015 2.15 1.92 0.10 0.13 35% 10.45 100
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Pricing Framework Wind
Incentives
IRR 17%
ROE 18.5%
Spread over LIBOR 4.5%
Spread over KIBOR 3.0%
Insurance 1% of EPC
O&M Costs US Cents 1.48/ kWh
Plant Factor 35%
Tariff Control Period 20 Years
Energy Benefit Sharing Mechanism 75%, 80% & 100% on each 1% increase on energy gain
TimelineOpt for Tariff 6 months from the date of issuance of determination
Financial Close One year from date of approval of upfront tariff
Construction Period 18 months from financial close
Coverage Inflation Risk, Exchange Rate Risk, LIBOR/ KIBOR change, Insurance etc
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Incentives for Generation Companies
Incentives (Small Hydro)
IRR 20%
ROE 27.4%
Spread over LIBOR 4.5%
Spread over KIBOR 3.5%
Tariff Control Period 30 years
Insurance 1.35% of EPC
Timeline
Opt for Tariff One year from the date of determination
Financial Close 18 months from date of acceptance of upfront tariff
Construction Period 36 months from financial close
Coverage Inflation Risk, Exchange Rate Risk, LIBOR/ KIBOR change, Insurance etc
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Response to Upfront Tariff
Technology Opted Upfront Tariff
– MW
In Operation Under Process
Wind 885 306 579
Baggasse 254 138 116
Solar 538 200 338
Coal 8,000 - 8,000
Small Hydel 150 - 150
• Coal and small hydel required longer time period 24-48 months for
achieving Commercial Operation. Similarly hydel power projects
required 4-6 years for achieving the COD.
• In addition to above 3600 MW on LNG, 1320 MW coal power projects,
3000 MW on hydel and 600 MW IPPs converted on coal through cost
plus basis has been allowed to charge such tariff which is approved by
NEPRA.
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Experiences with electricity Tariff Reforms
1999 2005 2006 2013 2014 2015
Tariff on
Cost-Plus
Basis
First
Multi-year
Tariff for
KESC
(K-Electric)
Upfront
Tariff for
Wind
Upfront
Tariff for
Bagasse
Upfront Tariff
for Solar and
other
technologies
Multi-year
Tariff for
Three other
Distribution
Companies
d d d d d d
2016 Onwards Tariff based on Competitive Bidding
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• Central Asia – South Asia (CASA) a comprehensive initiative tointerconnect Tajikistan, the Kyrgyz Republic, Afghanistan andPakistan to form a Central Asia-South Asia (CASA) RegionalElectricity Market through 500 KV, 750 KM HVDC line which willdeliver 1300 MW (300 to Kabul and 1000 MW to Peshawar).
• Import of 74 MW (Jackigur – Mand) - US Cents 6.5/kWh(depending upon oil prices)
• Import of 100 MW (Polan – Gawadar) – Under process
• Import of 1000 MW (Zahedan – Quetta) – Under process
Experiences with electricity Tariff Reforms - Generation
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Experiences with electricity Tariff Reforms - Distribution
• Determination of consumer-end tariff is determined on thebasis of following steps:
• Revenue Requirement: How much is needed?
• Cost of Service: What is the each class equitable share?
• Rate Design: How should rates be adjusted to reflect cost ofservice.
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Experiences with electricity Tariff Reforms
Description UnitsFinancial Year
2013-14 2014-15 2015-16
PPP-Unadjusted Rs. /kWh 11.30 10.25 8.70
Energy Comp
Fuel 7.2639 5.5199
V. O&M 0.2697 0.3063
Capacity 2.4955 2.5452
UOSC 0.2243 0.3241
Allowed Losses (National Avgerage) % 13.29% 15.27% 15.23%
PPP-Adjusted Rs. /kWh 13.00 12.10 10.26
Distribution Margin Rs. /kWh 1.04 1.43 1.43
PYA Adjustments Rs. /kWh(0.07) (1.26)
(0.78)
PPP Adjustments Rs. /kWh (0.16) 0.06 -
Avg. Determined Tariff Rs. /kWh 13.81 12.33 10.90
Avg. Notified Tariff by GoP Rs. /kWh 11.52 11.45
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Experiences with electricity Tariff Reforms - Distribution
• The revenue requirement for each Distribution Company isrecovered through the following consumer categories:
• Residential
• Industrial
• Commercial
• Single Supply for further distribution
• Agricultural
• Special Contract – Tariff (J)
• Others i.e. public lighting, railway traction etc.
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Experiences with electricity Tariff Reforms - Distribution
Customers Consumer Mix Consumption Mix Revenue Mix
%age
Domestic 81.3 41.0 34.7
Commercial 14.9 8.6 13.8
Industry 2.1 38.6 41.0
Tube-well 1.6 8.2 6.3
Others 0.1 3.5 4.2
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Experiences with electricity Tariff Reforms - Distribution
DESCRIPTION
Fixed Charge
LESCOFY 2014-15
Variable Charge (Rs./kWh )
Rs./kW/M.
NEPR Determined
TariffFY 2014-15
Subsidy Surcharge
Tariff Payable
by Consumer
Residential
Up to 50 Units 4.00 2.00 2.00
Load up to 5 kW - -
01-100 Units 9.25 3.46 5.79
101-200 Units 11.00 2.89 8.11
201-300 Units 11.00 0.80 10.20
301-700Units 13.33 2.67 16.00
Above 700 Units 15.00 3.00 18.00
• In order to minimize the cross subsidy one slab benefit wasintroduced:
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Experiences with electricity Tariff Reforms - Distribution
• Lahore Electric Supply Company (LESCO) one of the Distribution
Company examples is given hereunder:
Description Unit
Revenue Requirement
Recovered through tariff
Actual cost
% of Cross
Subsidy
No. of Consumers Million 4.1
Sales GWh 16,962
• Residential
Million
61,857 75,836 89%
• Commercial 15,961 14,216 112%
• Industrial 68,084 61,906 110%
• Single Supply 5,087 3,911 130%
• Agricultural 11,377 12,408 109%
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NEPRA Evolutionary Process & Way Forward
• After cost plus mode and Upfront tariff NEPRA is now moving
towards Competitive Mode wherein indicative tariff on specific
technology will be given for bidding.
• NEPRA has also open the transmission network to the private
investors. In this regard HVDC line tariff from Matiari to Lahore
is issued.
• NEPRA has also issued the two separate licenses to private
entities for transmission network
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NEPRA Evolutionary Process & Way Forward
• NEPRA has already issued the Multi-year tariff to the
Distribution Companies which are likely to be privatized.
• T&D targets has been set for the DISCOM. Similarly the O&M
cost and investment target have already been set vis-à-vis cost
benefit relation.
• For bringing efficiency DISCOM have been given timeframe for
achieving the targets.
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Experiences with electricity Tariff Reforms
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