• Afghanistan
• Bangladesh
• Bhutan
• India
• Maldives
• Nepal
• Pakistan
• Sri Lanka

• In this section
• Reforms in the Power Sector
• Regulatory Framework
• Utilities
• Demand and Supply
• Tariff Analysis
• Renewable Energy
• NEPRA`s main functions and responsibilities
• Standards and Guidelines for Tariff Determination
• Sari/Energy Reports, Studies and Presentations
• Useful Links

Pakistan

Energy Sector Overview

The power sector in Pakistan is a mix of hydel and thermal units dominated by two vertically integrated (in generation, transmission and distribution) public sector utilities, Water and Power Development Authority (WAPDA) and Karachi Electric Supply Corporation (KESC). In addition, there are two nuclear power plants KANUPP and CHANUPP, and a number of independent power producers (IPPs) and small power producers (SPPs) established since 1994. In June 2004 the total installed capacity in the country was 19522 MW.

Installed capacity of the system as at June 2004

 

 

Breakdown of capacity by operator as at June 2004

Besides these utilities, there are five central government agencies with responsibilities in the power sector, as given below in the table.
Government agencies in the power sector

Government Agencies	Their Responsibilities
Ministry of Water and Power	Take care of the sector’s affairs and manage issues of energy policy.
Private Power and Infrastructure Board (PPIB)	To facilitate private investors in the power sector; provide guarantees on behalf of government; assists the regulatory authority in determining and approving tariffs; and also an implementing agency for power policy.
National Electric Power Regulatory Authority (NEPRA)	To ensure fair competition and consumer protection.
Alternative Energy Development Board (AEDB)	To promote the exploitation of alternative energy resources such as small scale hydro plants, wind power and off grid generation plants.
Privatisation Commission	Deals with privatisation issues.

Post 1958

The electricity sector in Pakistan in the post-1958 period was dominated by two vertically integrated publicly owned utilities, WAPDA and KESC (Government being the operator as well as the regulator). The former has a national coverage, whilst the latter serves only the Karachi division and adjacent areas. WAPDA’s power plants are a mix of hydel and thermal units, whilst KESC’s are mostly thermal. The performance of these two remained satisfactory until the early 1980s. Afterwards the situation started deteriorating. Severe constraints in the availability of capital led to inadequate generation capacity and transmission infrastructure. Power supply lagged behind demand resulting in excessive shortage of electricity especially for the industrial and commercial consumers. Growth in power generation has been very substantial with an increase in aggregate supplies of approximately 12 percent annually from 1960 to 1995. However, over the same period per capita power availability has increased from 28 KWh to 444 KWh . The economy, in general, and the manufacturing sector in particular, were adversely affected.

Post 1980

Like many other developing countries, Pakistan announced a policy shift towards the private sector in early 1980s which was later enhanced by the structural adjustment programme under the supervision of the IMF and the World Bank. Consequently, private sector investment increased from 26 percent to 51 percent of total investment during 1978-88. However, most of the privatized companies were in manufacturing industry. Privatization in the banking, electricity, telecommunications and transport sectors was delayed because of lack of procedural clarity, fear of unemployment among workers and the consequential emergence of private monopolies resulting in increase in prices.

Mid & late 1990’s

However, during mid and late 1990s, Pakistan expanded the scope of its privatization programme to include infrastructure also with electric power sector at the top of the agenda. As it was realised that power generation and transmission capacity expansion and efficiency could only be achieved with the involvement of the private sector. The government in 1992 prepared the strategic plan for the privatisation of the power sector. The Policy objective was to improve efficiency by establishing a healthy and competitive infrastructure sector. Privatization of electric power sector was expected to spur economic growth and reduce fiscal deficits.  However this has been argued in a number of studies.

By late 1990’s an autonomous regulatory agency, National Electric Power Regulatory Authority (NEPRA) was created to introduce transparent and judicious economic regulation in the sector. NEPRA came into existence in December 1997. However, the situation so far has barely changed. WAPDA and KESC are still facing institutional and organisational weaknesses. The combined direct and indirect losses incurred by these utilities during the period 1996-2007 have created large fiscal deficits, being covered though taxpayers money and through borrowings [Kemal, et al. (2002)]. Given the lack of funds, supply is also lagging behind demand that is increasing at the rate of 7 percent per year, and the gap is going to increase in the years to come, as shown in the chart below.

 

The increase in the demand however, is an indication of the expansion in the Pakistan economy. Both demand projections as well as international experience have suggested that power demand is likely to grow faster than the economy in the years to come [Parish (2006)]. Growth in demand suggests that substantial investment will be needed to maintain continuity of supplies. Not only in generation, the most capital intensive segment in the sector, investments are also needed in the transmission and distribution sectors to overcome the huge losses the sector is suffering for the last couple of years. Time line of important developments in power sector has been provided in the table below.
Time line of important development in Power sector

Year	Description
1975	The Pakistan Council of Appropriate Technology (PCAT) established.
1981	National Institute of Silicon Technology (NIST) established.
1988	Private sector investment increased from 26 percent to 51 percent of total investment.
1992	Government prepared the strategic plan for the privatization of the power sector
1992	National Pakistan Conservation Strategy (PNCS) was enacted, which was subsequently integrated into the ninth Pakistani energy plan (1993-1998).
1994	Government formulated a power policy and invited independent power producers (IPPs), for the first time, to invest in the generation part of the power sector.
1994	Private Power and Infrastructure Board (PPIB) was established to facilitate private investors.
1996	Kot Addu Power Plant (1638 MW) was the first to be privatized
December, 1997	Autonomous regulatory agency, National Electric Power Regulatory Authority (NEPRA) was created.
1998	Unbundling of WAPDA’s, a vertically integrated Power Wing, into separate generation, transmission, and distribution companies
1998	NEPRA prescribed in Tariff Standards and Procedures Rules (1998) for determining tariffs.
2000	NEPRA was directly attached with the Cabinet Division.
May, 2001	NIST and PCAT merged to become the Pakistan Council for Renewable Energy Technology (PCRET).
2001	Automatic Tariff Adjustment (ATA) mechanism for fuel cost variations adopted and applied every three months.
2002	NEPRA approved a framework of multi-year tariff for KESC, for seven years from its privatization (in view of its expected privatization in the near future).
May, 2003	The Alternative Energy Development Board (AEDB) was established.
2004	NEPRA approved a CPI-X based MYT framework with an initial duration of five years for FSECO.
2005	A majority stake (73 percent of shares) in KESC was sold to a private investor

Reforms in the Power Sector

The government in 1992 prepared a strategic plan for restructuring the electricity sector. In 1994, the government formulated a power policy and invited for the first time, independent power producers (IPPs) to invest in the generation part of the power sector. As a result of attractive government incentives and generous tariff offers 19 IPPs started their operations in Pakistan. They brought over $3 billion to install about 3500 MW capacity. These IPPs were allowed to sell electricity to both WAPDA and KESC under power purchasing agreements (PPAs). Hub Power Plant (HUBCO) was the first one to start its operation in 1993, with a capacity of 1292 MW and a negotiated tariff based on a “cost plus” approach. From 1998 onwards, Pakistan had excess capacity, as WAPDA and KESC were restricted to purchase expensive IPPs electricity while their own plants were underutilised. Financial problems instead of improving deteriorated even further. IPPs get involved in disputes and litigation with the government over the rates set in their PPAs with WAPDA.  In response to the Governments demand for a rate reduction, IPPs demanded that prices for fuels be lowered. The government however later resolved the IPP issues with the involvement of international donors and within the framework of contractual agreements. The structural adjustment programme under the supervision of IMF and WB later enhanced this policy shift.

Other steps taken as apart of the reform process included:

1. Establishment of National Electric Power Regulatory Authority (NEPRA), under NEPRA Act 1997, an autonomous regulatory agency, to ensure transparent and judicious economic regulation in the power sector.
2. Private Power and Infrastructure Board (PPIB), was established in 1994, to facilitate private investors.
3. Unbundling of WAPDA’s vertically integrated Power Wing into separate generation, transmission, and distribution companies (as in the 1998 WAPDA Act) in 1998. WAPDA has now been reorganised into four thermal generation companies called GENCOs, nine distribution companies called DISCOs, and one National Transmission and Dispatch Company (NTDC). The hydroelectric power development and operation functions remain with WAPDA. (Further details section 4)

Current market structure in Pakistan

1. Pakistan Electric Power Company Private Limited (PEPCO) a separate agency within WAPDA is made responsible for the restructuring and preparation for privatisation for the generation and distribution companies in due course through the Privatisation Commission. Private sector participation is being encouraged to promote competition in the generation and distribution parts of the industry, while, NTDC would remain under state control and be responsible for national dispatch, transmission, and system planning as a ‘single buyer’.
2. Responsibility for the energy sector policy remains with the government.

The process of separating out various entities and corporatisation is in progress. While unbundling has been completed, the various entities created from WAPDA still lack independence from WAPDA and from one another. The distribution companies are still financially integrated with WAPDA, lack the technical skills to operate independently, do not have notified tariffs and have managers that are WAPDA employees [Parish (2006)]. However, in Pakistan the overall performance of the power sector and its institutions in the last 15 years has been moderate.

Regulatory Framework

Initially, National Electric Power Regulatory Authority (NEPRA)-1997 was established as an autonomous body without any administrative control from the government. However, for the sake of interaction with Federal and Provincial Governments it was initially attached to the Ministry of Water and Power. Later it was linked with the government through the Ministry of Law and Justice. However, in June 2000 NEPRA was directly attached with the Cabinet Division. Currently, NEPRA is working in an extremely centralised manner. All the decisions regarding tariffs and standards need to be approved by the government. It consists of a Chairman and four members (one from each province), all appointed by the government.

The initial funding of NEPRA was provided through a grant from the Federal Government amounting to Rs 100.5 Million. In addition, NEPRA is expected to meet its expenses from licensing fees on constant basis and filling fees for tariff applications etc. Just like any regulatory system, the most important regulatory functions of NEPRA are grouped in the following five main categories (details in Appendix A).

1. Determination of tariff rates and terms and conditions
2. Grant of licenses, approval of power acquisition programmes
3. Setting and enforcement of quality-of-service standards, approval of operating codes  and investment standards
4. Industry structure/privatisation including the transition towards a competitive market  where feasible
5. Consumer rights and obligations, complaint redressal

NEPRA’s broad policy guidelines for power sector reforms revolve around:

1. Tariff structure to ensure sufficient resources to cover costs and investment in the short term
2. Encourage generation, transmission and distribution capacities on a non-discriminatory basis to meet the existing needs and growing demand in the long run
3. Quality of service to the consumers as well as ensuring network efficiency including reliability and voltage disturbances

Privatisation as such is not directly the function or responsibility of the NEPRA. But NEPRA has to facilitate the process to bring efficiency in the power sector and helps in ensuring competition where feasible. The privatisation process started at a slow speed. Kot Addu Power Plant (1638 MW) was the first to be privatised in 1996. Initially 26 percent of the shares were transferred to the private owner, and then later on 10 percent more of the shares were transferred to the private owner. In December 2005 a majority stake (73 percent of shares) in KESC was sold to a private investor. It is the major step although the process took many years to materialise. Next in line is the distribution company, FESCO. It was intended to sell 56 percent of its shared capital by the second quarter of 2006 but so far nothing has happened. It is because of the delay in the notification of the tariff approved by NEPRA. A multi year tariff has already been determined for JPC. All the short listed bidders for these companies, who had invested their time and money in carrying out the due hard work, are waiting for the resolution of the dispute between the Government and NEPRA. This is a major setback for the companies waiting for their privatisation.

Utilities

A. WAPDA

The primary development role of WAPDA has been revived. It is now focusing only on hydel development and water sector projects to support the national economy and poverty alleviation through improved hydel-thermal mix of power generation, provision of electricity at affordable price and most pertinently perspective planning and timely execution of projects to meet the water and power demand of the growing population, agriculture and industry of the country.

Installed Capacity of WAPDA System (as of June 2007)

WAPDA has now undertaken ‘Vision 2025’ Programme comprising a comprehensive integrated water resources and hydro power development. Five Mega hydropower projects have been announced by President of Pakistan which is to be completed by 2016 with generation capacity of 9,500 MW. The total cost of these Projects will be US$ 20.3 Billion. Two projects are ready for awarding construction works whereas three Projects are in the stage of feasibility studies and preparation of tender documents. In addition to above, there are 14 new Projects which are under study for construction with generation capacity of 20,770 MW with expected construction cost US$ 32.15 Billion. The Projects will be located on river Indus and its tributaries.

Power wing of WAPDA comprising of Generation, Transmission and Distribution has been restructured into fourteen (14) public limited companies, four power generation companies, one National power dispatch company and nine distribution companies. Power wing is currently headed by Member (Power). These fourteen (14) Corporate Entities are:-

1. Thermal Power Generation Companies (GENCOs)

1. Southern Generation Power Company Limited (GENCO-1) head quarter at Jamshoro district Dadu near Hyderabad Sindh.
2. Central Power Generation Company Limited (GENCO-2) head quarter at Guddu district Jacobabad Sindh.
3. Northern Power Generation Company Limited (GENCO-3) head quarters at TPS Muzaffargarh district Muzaffargarh Punjab.
4. Lakhra Power Generation Company Limited (GENCO-4) Headquarter at WAPDA house Lahore.

2. National Transmission & Power Dispatch Company (NTDC)

3. Distribution Companies (DISCOs) as under:
I. (LESCO) - Lahore Electric Supply Company
II. (GEPCO) - Gujranwala Electric Power Company
III. (FESCO) - Faisalabad Electric Supply Company
IV. (IESCO) - Islamabad Electric Supply Company
V. (MEPCO) - Multan Electric Power Company
VI. (PESCO) - Peshawar Electric Power Company
VII. (HESCO) - Hyderabad Electric Supply Company
VIII. (QESCO) - Quetta Electric Supply Company
IX. (TESCO) - Tribal Electric Supply Company

B. KESC

The Karachi Electric Supply Company Limited was incorporated on 13th September 1913 under the Indian Companies Act, 1882 as amended to date vide the Companies Ordinance 1984. The Company is listed on Karachi, Lahore and Islamabad Stock Exchanges. The Government of Pakistan took control of the Company by acquiring majority shareholding in 1952. The Ministry of Water and Power looks after the affairs of the Company at Federal level.

The Company is principally engaged in generation, transmission and distribution of electric energy to industrial, commercial, agricultural and residential consumers under the Electricity Act, 1910 as amended to date and NEPRA Act 1997, to its licensed areas. The licensed area of KESC is spread over entire Karachi and its suburbs up to Dhabeji and Gharo in Sindh and over Hub, Uthal, Vindhar and Bela in Baluchistan. The total area covered is around 6000 square kilometers.

The privatization of the Company has been finalized in November 2005 with the transfer of 73% shares of Government of Pakistan along with management control to the new owner viz M/s KES Power & others. The new management has taken over the charge of the Company, with effect from November 29, 2005. Further, an Implementation Agreement was entered into between the Government of Pakistan and the Company, setting out the key terms and conditions of the take over.

New investors include KES Power Limited, Hassan Associates (Private) Limited and Premier Mercantile Services (Private) Limited who hold 71.5%, 1.00% and 0.5% shares in the capital of Company, respectively.

The new management has employed M/s. Siemens Pakistan Engineering Limited as the Operations and Management (O&M) Contractor for the operation and management of the Company. The objective was to make the Company a profitable entity within next two years. In this regard M/s. Siemens undertook the process of updating and modernizing the infrastructure and operations of the Company.

i. Generation – Expansion & Rehabilitation

Injection of efficient and economic generation in KESC system has been an integral component of the turn around strategy pursued by the owners since privatization of the Company in disregard of its unfavourable commercial impacts in the face of high system losses and mis-match between rising cost of prime inputs and applicable tariff. The last addition in generating capacity of KESC was made back in 1997 when BQPS unit-6 of 220 MW was commissioned. Further, a 830 MW power plant at BQPS was approved by the Board as early as June 2006, which contract unfortunately could not be finalized.

Contract for setting up 220 MW combined cycle power plant at KTPS was awarded in January 2007. Gas Turbine Units-1 & 2 have already been synchronized with the system and are undergoing various commissioning tests, whereas third and fourth GTs of identical generating capacity are likely to be commissioned by November 2008 and Steam Turbine of 26.378 MW would be operative in July 2009.

Contract for setting up new power plant phase-II BQPS extension of 560 MW combined cycle project has been awarded in June 2008. The project comprises of three-GTs of 128.90 MW each (ISO capacity) and one (1) Steam Turbine of approximately 185 MW and the project is likely to be commissioned in the year 2010-11. De-rating of the existing generating capacity spanning over last couple of decades has been arrested through a systematic maintenance and rehabilitation plan as a result of which generating capacity has been enhanced by approximately 190 MW.

ii. Transmission and Distribution Network – Expansion & Rehabilitation

An outdated and dilapidated transmission and distribution infrastructure was inherited by the owners and overloading of the twin networks was also responsible for high technical energy losses in the transmission & distribution system in addition to administrative losses. Strategic Plan with implementation mechanism was prepared for rehabilitation of transmission and distribution network which has been under execution in a phased and prioritized manner. A number of critically important projects have been commissioned or are in the final stage of completion which have relatively improved network reliability and increased transmission & distribution capacity and reduced technical losses. During the year under review the following four (4) GIS grid stations were completed and commissioned:

1. 220 KV Baldia Grid Station (Extension)
2. 132 KV West Wharf Grid Station (New)
3. 132 KV Old Town Grid Station (New)
4. 220 / 132 KV KDA Scheme 33 Grid Station (Extension)

Whereas nine (9) 132 KV GIS Hybrid Grid Stations are in various stages of completion and shall be commissioned in a phased manner by 17 November 2008 which would further improve network reliability and capacity of the transmission network. However, considering the degree of fragile and dilapidated T&D infrastructure inherited by the new management, the improved results in tangible form such as improvement in system stability and voltage profile, enhanced transmission capacity & flexibility, reduction in overloading of power transformers & 11KV feeders and load-shedding would be more visible in the near future. 61 KM of 132 KV underground cables have been laid and energized during the year under review, whereas another 117 KM is under execution which would further augment and improve the transmission network. Establishment of computerized system for management of generation, transmission and distribution known as SCADA had been planned and is being executed as one of the prioritized projects, fifty percent (50%) progress has been achieved and provisional taking over of the project is scheduled by 31 March 2009. The commissioning of this critically important project would significantly improve efficiency of power system control & monitoring, facilitate timely operational decisions & economic dispatch of power and would minimize outages and technical losses. During the FY 2008 review, distribution system has been augmented & expanded through addition of 151,443 KM 11KV overhead & 334,972 KM underground lines and 889,101 KM 400V overhead & 85,790 KM underground lines and 2204 11KV distribution substations / PMTs. The 11KV distribution capacity has been increased by 127,375 MVA (3%) from 4,310,515 MVA to 4,437,890 MVA.

Demand and Supply

With the induction of IPPs, although Pakistan have been able to meet the electricity demands of the country and getting rid of the load shedding, yet high tariff compelled the industry to install their own captive power projects. This resulted in surplus power of approximately 2000 MW (1000 MW in peak hours and 2000 MW in non-peak hours) during 1999-2000.

However, the surplus power disappeared during 2004-2005. There will be an additional demand of 5500 MW upto the year 2010, for which the power policy of 1998 is being reviewed to make it more attractive sector investment.

Projection for Demand and Supply

Source: Ministry of Water and Power, Pakistan

Future Projects, following two major projects are under process for approval.

Following prospective hydel power potential can be implemented in future:

Tariff Analysis

Tariffs or electricity pricing is an important regulatory component. NEPRA determines tariffs as prescribed in Tariff Standards and Procedures Rules (1998), keeping in view the principle to cover costs and reward investments as applicable on a case to case basis (for details see Appendix B). The current tariff structure is based on rate of return or cost of service. It determines prices charged so as to achieve revenues that cover all legitimate operating and capital costs while providing the firm with a fair rate of return on its capital employed. This fair rate of return is related to the cost of capital and is similar to delivering the economist’s normal profit.

Since March 2001, an Automatic Tariff Adjustment (ATA) mechanism for fuel cost variations has been adopted, and applied every three months, i.e., adjusting consumer end tariff of the distribution companies in order to account for variations in the price of fuel. The idea is to capture the volatility of fuel price variations. NEPRA has decided the generation tariff for SPPs. Generation tariff to the three generation companies unbundled from WAPDA has been granted after approval from the government. NEPRA also granted NTDC with their use of system charge tariff and approved a list of generation companies selling electricity to the Central Power Purchase Agency (CPPA) for onward sale to the DISCOs according to their respective demands (same has been provided in the table below). Hydel tariff for WAPDAs hydel generation plants has also been approved.

Merit order by NTDC
Based on the Present Net Heat Rate at 100% Plant Factor (as per June 22, 2005)

Merit Order Criteria Based on the Present Net Heat Rate for KESC
(As per June, 2005)

Sr No.	Plant Groups	Fuel Type	Fuel Cost Rs/kWh	O&M Cost Rs/kWh	Specific Cost Rs/kWh
	Thermal
1	Bin Qasim Thermal Power Station	Gas/F. Oil	2.381	0.236	2.617
2	Korangi Thermal Power Station	Gas/F. Oil	2.799	0.202	3.001
	Gas Turbines
3	Site Gas Turbines	Gas/HSDO	2.97	0.967	3.937
4	Korangi Gas Turbines	Gas/HSDO	2.862	0.211	3.073
	Total		2.481	0.223	2.705

Source: KESC

The average end user tariff in Pakistan for fiscal year 2005 is estimated to be around 3.93 Rs/KWh. It involves significant cross subsidies, from industrial and commercial consumers to agricultural and small (under 50 kWh per month) domestic consumers. Tariff structure is consistent throughout the country but is (besides cross subsidies) divided by consumption levels (tariff slabs); and for industrial consumers, it is divided into peak and off-peak charges.

The ATA for ex-WAPDA distribution companies was stopped from December 2003 as all distribution companies have applied separately for their tariffs. Detailed determinations of tariff review motions filed by the 8 DISCOs were issued in November 2004. As per the requirements in the determinations a mid year review of the tariff was conducted and tariff adjustments were made in February 2005. The increase in tariffs for IESCO, FESCO, LESCO, MEPCO, GEPCO, PESCO, HESCO and QESCO in Ps/kWh was 13.25, 12.22, 8.98, 10.32, 15.15, 11.81, 5.95, and 12.99 respectively. However, this is still waiting for government notification.

NEPRA has the credit to establish for the first time in South Asia a CPI-X based multi-year tariff (MYT) regulatory framework. In 2002, NEPRA approved a framework of multi-year tariff for KESC, for seven years from its privatisation (in view of its expected privatisation in the near future). Secondly, in June 2004, NEPRA approved a CPI-X based MYT framework with an initial duration of five years for FSECO, in view of its expected privatisation. A multi year tariff has also been determined for JPC. This new framework is a radical shift from the rate of return regulation regime to performance based regulation in the power sector of Pakistan [Raza (2003, 2004)].

Some of the amendments made in the tariff rate structure are: cross subsidies have been reduced by increasing the rates of subsidised classes; flat rates have been abolished; consumer bills have been simplified to include all the surcharges and additional  surcharges in the overall rates in such a manner that only fixed and energy charges are reflected in consumer bills; consumers have been protected from frequent price variation by allowing only quarterly adjustment for fuel price adjustment; and unjustified demands of the utility such as charging on the basis of connected load and increase of rates to cover for inefficiencies has not been allowed.

Another issue is current tariff levels and structures involving significant cross subsidies, from industrial and commercial consumers to agricultural and small (under 50 kWh per month) domestic consumers. Although tariff increase for domestic and agriculture consumers exceeded that for the CPI (consumer price index), and other consumer categories in the period from 1991 to 2005, limited progress has been made in reducing cross-subsidies. The largest percentage increase in the revenue collected per kWh occurred in the agriculture sector, followed by the domestic sector. The revenues collected in these two sectors are still considerably lower than for other consumers, and less than one half of those for commercial users. In this period from 1991 to 2005, the rate of power tariff increase outstripped inflation (as shown in table below). While tariff charged to the domestic consumers is cross-subsidised from industrial and commercial consumers, the share of electricity sold to domestic consumers has increased from 31.6 percent in 1988-89 to 43.6 percent in 2004-05.  This subsidised category has created an additional burden on the financial position of public utilities. These will continue to be necessary so long as the tariff structure is not developed to cover costs.

Nominal Tariff in Paisas per KWh

Source: Kojma (2006), Malhotra, et al.(1994), FESCO Report (2006) and International Financial Statistics (Various Issues)

WAPDA generates about 60 percent of the country’s electricity, while KESC provides about 12 percent; the rest comes from IPP’s and other sources. The losses of these companies are so huge that subsidising them each year is an enormous burden on the federal budget.

Other update on Tariff:-

1. NEPRA on January 11, 2008 arrived at a levelized indicative tariff of 7.8055 cents/kWh or 4.7613 Rs./kWh for Coal based power plants. This Indicative Tariff for Coal based power plant was in compliance with the directions of Economic Coordination Committee of Cabinet in its decision  No. ECC-187/2007 dated 12.12.2007

1. NEPRA on May 15, 2008 arrived at a revised upfront tariff of 9.5000 cents/kWh or 5.7000 Rs./kWh for Wind Energy Generation. This Revised Upfront Tariff for Wind Energy Generation was in compliance with the directions of Economic Coordination Committee of Cabinet in its decision No. ECC-187/2007 dated 12.12.2007

Renewable Energy

Pakistan’s first promotion measures for renewable energy sources were implemented in the early 1980s. The sixth Pakistani energy plan (1983–1988) devoted approximately €14 million to the areas of renewable energy crops, biogas and a feasibility study for the commercial exploitation of solar energy. The Pakistan Council of Appropriate Technology (PCAT, established in 1975) and the National Institute of Silicon Technology (NIST, established 1981) were jointly responsible for implementing the measures. While PCAT focused its attention primarily on the areas of mini-hydropower, biogas plants, solar cookers and small wind energy conversion systems for driving water pumps, NIST was more involved in the research, development and commercialisation of solar energy with focus on photovoltaic. For lack of precise promotion instruments, the output of all solar and wind energy systems plus mini-hydropower plants together amounted to less than 5 MW at the end of the 1980s.

The 1990s also saw some isolated instances of promotion measures for renewable energy sources in Pakistan, but they were all very limited in their financial scope. In this connection, mention could be made of the 1992 National Pakistan Conservation Strategy (PNCS) which was subsequently integrated into the ninth Pakistani energy plan (1993-1998). Altogether, PNCS spent some 63 million rupees (€ 900,000) on introducing biogas, wind power and mini hydropower facilities.

A. Pakistan Council for Renewable Energy Technology (PCRET)

The latest alternative energy promotion activities in Pakistan again encompass institutional measures and define target objectives. In May 2001, the two separate research institutions NIST and PCAT merged to become the Pakistan Council for Renewable Energy Technology (PCRET), the main goal being to better coordinate research activities and avoid overlaps.

B. National Environment Action Plan – Support Programme (NEAP-SP)

The Support Programme (NEAP-SP) for implementing the National Environment Action
Plan (NEAP) of 1997 was signed by the Government of Pakistan and UNDP in October
2001. The NEAP-SP includes six different sub programmes, one of which concerns the field of energy conservation and renewable energy sources, and concrete projects are to be implemented over the next five years.

C. Alternative Energy Development Board (AEDB) 

The Alternative Energy Development Board (AEDB) was founded in May 2003 for supplying wind- solar and mini/small hydropower generated electricity in remote regions of Pakistan. AEDB is also responsible for developing the country’s medium- and long-term promotion policy for renewable energy sources. In addition, its functions include the coordination of joint ventures with the aim of having foreign technologies in the field of alternative energies fabricated in Pakistan. The AEDB is located in Prime Minister Secretariat and answers directly to the cabinet division and the Prime Minister. The AEDB has a mandate of 10% of the total installed capacity in the country from Renewable Energy sources by 2015.

D. Status of Renewable Energy Sources 

i. Hydropower

Pakistan’s total hydropower potential has been estimated over 40,000 MW, some 24,000 MW of which could be easily harnessed, and approximately 6400 MW of which is actually being exploited.  More than 1000 MW micro/mini hydropower potential is available in northern mountainous region of the country, of which less than 1% is being developed. Due to anticipated growth in demand and of the fact that only about 20% of the available hydropower potential is being utilised, the ‘Vision 2025’ development plan provides first and foremost for the vigorous, multi-stage development of hydroelectric power.  

a. Run-of-river Ghazi-Barotha power plant

Ghazi-Barotha Power Plant, a run-of-river plant that is presently being commissioned in successive stages, constitutes an initial large-scale project in this sector. Located on the upper reaches of the Indus and built for a total output of 1,450 MW, its first stage (290 MW) went into service last July. The power station was fully commissioned in mid-2004. The project is being implemented under the auspices of state-owned WAPDA. The total cost of the project stands at roughly US$ 2.1 billion. The project is being financed by the World Bank, the Asian Development Bank and the Japan Bank for International Cooperation (JBIC), the European Investment Bank, the Islamic Development Bank, and resources from German Financial Cooperation (KfW). WAPDA is contributing approximately US$ 1 billion, or nearly half of the overall cost. Fully utilised, the power plant is supposed to lower CO2 emissions by approximately 5.5 million tons annually.

b. GTZ assistance for medium-size hydropower projects

In addition to the aforementioned large-scale project, three additional hydroelectric power plants of medium size – the high-pressure plants Allai Khwar (121 MW), Khan Khwar (72 MW) and Duber Khwar (130 MW) – have been prepared with GTZ assistance in recent years. The GTZ conducted the feasibility studies and generated the tendering documents for all three projects. The Abu Dhabi Development Fund is providing credit to the amount of US$ 150 million for implementing the projects. Pakistan itself is raised additional funds and all the projects are under construction.

ii. Micro hydropower potential

In northern Pakistan alone there is an estimated potential of 300 MW for micro hydropower plants with installed capacities below 100 kW each. As of today, only about 10 MW of that potential had been tapped by a total of some more than 300 projects co-financed by Aga Khan Rural Supprt Programme (AKRSP) PCRET, European Union (EU) and private developers. Now, with the assistance of the Asian Development Bank and within the scope of Malakand Rural Development Project, 100 micro hydropower plants with ratings ranging from 5 to 50 kW are under implementation with in and around Malakand Division of the North-West Frontier province (NWFP).

iii. Wind Energy

By the end of 2003 not a single wind energy conversion system with a generating capacity above 500 W had been installed in Pakistan. There are only a small number of micro-plants (300–500 W) for generating electricity, and roughly 30 wind power installations are in use for pumping water in the coastal regions of Balochistan and Sindh provinces. Most notably along its 900 km coastline and in a number of North-West Frontier valleys, Pakistan possesses about 50,000 MW of economically exploitable wind-power potential. On commercial grid connected electricity generation programme, the Government of Pakistan has decided to install 100 MW wind power farm during the year 2005. This programme initiated by the AEDB involves financing through private sector, land from Government of Sindh and power purchase by NTDC for HESCO/KESC. The Government of Pakistan guarantees are backed through NEPRA. The Board has issued LOIs to 22 national and international companies for generation of 1100 MW power through wind energy. With the help of AEDB Pakistan also plans to install an additional 300 micro-wind turbines with a high domestic content by 2003/2004.

iv. Biomass

In Pakistan, where, according to the last census from 1998, approximately two out of three people live in rural areas, the rural residents in particular rely almost exclusively on biomass in the form of fuel wood or charcoal for cooking and heating. Indeed, the majority of Pakistan’s urban population (58%) also takes recourse to those traditional sources of energy. According to official data, the country’s total wooded area expanded from 34,600 km2 to 38,100 km2 (i.e. by about 10%) between 1990/91 and 2001/02, but each year local residents remove some 1.2 million m2 of wood from the country’s forests for use as fuel. In Balochistan, this practice has reduced the total area of standing forest by 70%.

v. Solar Energy

Pakistan has a very good overall solar-energy potential. The average daily insolation rate amounts to approximately 5.3 kWh/m2. Especially the south-western province of Balochistan offers excellent conditions for harnessing solar energy. There, the sun shines between 8 and 8.5 hours daily, or approximately 3,000 hours per annum. Despite these favourable prerequisites, the use of solar energy for generating electricity or for heating is still in its beginnings. Photovoltaic systems are used primarily for producing electricity in rural areas. As far back as the early 1980s, the Government of Pakistan had 18 PV systems with a composite output of 440 kW installed in various parts of the country. Due to the lack of technical know-how about their operation and maintenance, though, no further systems were installed. For the same reason, seven other PV systems with a total output of 234 kW, which were installed in the Pakistani part of the Hindu Kush in the late 1980s, are no longer in operation. However, with the establishment of AEDB, this time round will ensure sustainability of such projects by providing a workable model on commercial lines.

 vi. Geothermal Energy

Although there are numerous hot springs with temperatures ranging from 30°C to 170°C to be found in various parts of Pakistan, for example in the vicinity of Karachi and in the Pakistani part of the Himalayas, there has been no attempt to make use of geothermal energy in Pakistan yet.

APPENDIX A

NEPRA`s main functions and responsibilities

1. Issuing of licensing for generation, transmission and distribution of electric power.
2. Enforcement of quality standards and ensuring of safety in the operation and supply of electricity to consumers.
3. Determine tariffs for generation, transmission and distribution of electric power.
4. Approving the investment and power acquisition programmes of the utility companies.
5. Setting fees for licenses and its renewal, fines for breaking the rules.
6. Setting a uniform system of accounts for generation, transmission and distribution companies.
7. Setting and reviewing the performance standards of all companies.
8. Inform government about the activities of power companies.
9. Encourage uniform industry standards and code of conduct for generation, transmission and distribution companies.
10. Tender advice to public sector projects.
11. Report to the federal government on all activities relating to generation, transmission and distribution.
12. Perform any other function incidental or consequential of the abovementioned responsibilities.

APPENDIX B

STANDARDS AND GUIDELINES FOR TARIFF DETERMINATIONS

According to Section 17, NEPRA Tariff Standards and Procedures Rules 1998, tariffs will be determined in accordance with the following standards:

1. Tariffs should allow licensee the recovery of all costs. It may not require assessing the licensee where tariffs are set on other than cost of service basis, such as formula based tariffs that are designed to be in place for mo re than one year

2. Tariffs should generally be calculated by including a depreciation charge and rate of return on the capital investment of each licensee equal to that earned by other investments of comparable risk

3. Tariff should allow a rate of return which promotes continued reasonable investment in equipment and facilities for improved and efficient service

4. The mechanism of tariff should allow licensee a benefit as well as penalty in case of failure to provide the service and the quality of service

5. Tariffs should reflect marginal cost principles to the extent feasible, keeping in view the financial stability of the sector; the preference of the authority is for competition rather than regulation therefore, tariff policies should be directed towards that end

6. The tariff regime should clearly identify interclass and inter-region subsidies and provide such subsidies transparently if found essential, with a view to minimising if not eliminating them, keeping in view the need for an adequate transition period

7. Tariffs may be set below the level of cost of providing the service to consumers consuming electric power below the consumption levels determined for the purpose from time to time by the authority, as long as such tariffs are financially sustainable

8. Tariffs should reflect the full cost of service to consumers groups with similar service requirements

9. Tariffs should take into account government subsidies or the need for adjustment to finance rural electrification in accordance with the policies of the government

10. The application of the tariffs should allow reasonable transition periods for the adjustments of tariffs to meet the standards and other requirements including the performance standards, industry standards and the uniform codes of conduct

11. Tariffs should seek to provide stability and predict ability for customers

12. Tariff should be comprehensible, free of misinterpretation and shall state explicitly each component.