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SCHEDULE 1

MINIMUM FUNCTIONAL SPECIFICATIONS

The Complex consists of 4 Kaplan bulb turbine generator units (each referred to as a “Unit”)

with installed plant capacity of 84MW measured at generator terminals.

The Site is located at the tail end of the Bong Canal, about 8 km downstream of Mangla Dam,

near the New Bong Escape about 120 km south east of Islamabad, the Capital of Pakistan. The

climate of the Project area is characterized by four distinct seasons, winter from mid-November

to February, spring during March and April, summer from May to mid-September and autumn

from mid-September to mid-November.

Average annual rainfall at Jhelum and Mangla based on records of more than thirty (30) years is

852 mm and 850 mm respectively; most of the annual rainfall (above 60%) occurs during the

monsoon season (July-September) while the dry period is October and November.

A minimum earthquake design factor of 0.2 g for ground motion acceleration will be utilized for

structural and geo-technical design of the plant buildings and various components of the Project

structures; the design wind speed will be 160 km/hr.

The powerhouse site will generally be at an elevation of 254.5 m (835 feet) with respect to

Survey of Pakistan Datum (SPD). Access to the Site will be provided by the existing metal road

from Dina-Mangla via Bong Canal road.

The turbines and generators are housed within water-tight bulb-units which are placed in the

water passage. The powerhouse contains electrical, control and balance of plant equipment while

transformers are placed outside at the transformer deck of the powerhouse. The other plant,

buildings and structures include headrace channel, concrete lined where required, intake

structure, stop logs for intake, , draft tube stop logs, tailrace channel, 132 kV GIS located at

Power Station structure consisting of breaker and a half arrangement, Interconnection and

Transmission Facility, stores, offices and staff colony.

The Complex will use water from the Bong Canal, excluding the water allocated for the Upper

Jhelum Canal up to its maximum capacity of 354 m3/s (12,500 cusecs), drawn from the inlet in

the Bong Pond and passed through the powerhouse water passage into the headrace channel

creating a gross head of approximately 9.82 m (32.22 feet) with a plant flow rate of 1012 m3/s

(35,733 cusecs).

Each Unit shall be designed to operate independently and together with other Units in the

Complex in parallel over a wide range of operating conditions within the Technical Limits.

The Complex shall be capable of operation within a voltage range of ± 10 % on the 11 kV

system and 132 kV system.

The generators shall be synchronous, air-cooled, bulb-type, directly coupled to the bulb turbines.

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Pressurized air shall be circulated axially through the bulb for cooling the windings.

The rating of each generator will be as follows

Nominal capacity 26.25 MVA

Speed 100 rpm

Power factor 0.8 lagging ; 0.9 leading

Frequency as per NTDC Grid Code

2005

Voltage 11 kV

Insulation Class F

Short circuit ratio > 1.0

Each generator shall be connected to a transformer on a Unit basis located outside the power

station and a total of 4 transformers will be provided for the Complex plus one spare transformer.

Each three-phase transformer shall be provided with the following ratings:

Nominal capacity 26.4/28.0 MVA

Cooling ONAN/ONAF

Frequency 50 Hz

Voltage ratio 13.2/1

Winding connection YNd11

Maximum winding temperature rise 65 C

Tap changer type Off Load

Single phase XLPE cables (3× 500mm²) will be used for making connections between generator

terminals, generator voltage switchgear and low voltage winding of generator step–up

transformers.

Interconnection with the Power Purchaser’s system will be via an in – out arrangement with both

circuits of an existing 132 kV double circuit Mangla–Kharian line. An outdoor 132 kV GIS

having double bus and breaker and a half arrangement will be used. Breakers will be SF6 type.

High-voltage connections between each main transformer and GIS shall be made with GIS Busbars.

A common control room shall be provided to monitor and control the Complex and the operation

of the New Bong Escape. The plant control systems will include a data acquisition system, auto

and manual controls, protection for turbines, generators, transformers, switchyard equipment and

lines, displays, annunciations, alarms and metering system based on the latest state – of – the –art

technology will be provided. The control system shall be capable of providing discharge values

computed from power and water levels, headrace level, tailrace level, load vs discharge curves,

total volume of water passed through turbines, conditions before and after tripping, sequence of

events and temperatures.

All permanent material, plant, equipment and machinery incorporated in the construction of the

Complex shall be new and unused.

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SCHEDULE 2

TECHNICAL LIMITS

1. Design Limits

1.1 Unit Starts

The length of notice required by the Company to start-up the Complex and synchronize

to the Power Purchaser Grid System will be fifteen (15) minutes for normal operating

conditions. The length of notice required to start–up the Complex, including oil systems,

and synchronize to the Power Purchaser’s Grid System will be thirty (30) minutes in the

event that the turbine shutdown has involved shutdown of the turbine oil systems.

1.2 Complex Loading

(a) The Complex load ramping rate is the steady rate at which the load can be raised.

The maximum load ramping rate should not be more than 50% per minute.

(b) Complex load percentages in this Schedule refer to the load at the generator

terminals as a percentage of gross capacity.

(c) The Complex can withstand a full load rejection and remain in a safe operating

condition and the Complex auxiliaries shall be kept in operating conditions

continuously. Further, the Complex shall be re-synchronized within fifteen

minutes provided that the reason for the load rejection has been removed.

(d) The Complex minimum continuous loading shall be 7.35 MW.

1.3 Complex Load Rejection and Maintenance of Headrace Water Level

(a) The Complex shall be operated in a manner to ensure that the water level of New

Bong pond shall be maintained at 254.45 m ± 0.061 m (834.8 feet ± 0.2 feet)

under normal load acceptance or Unit shut down conditions.

(b) Sudden load rejection of the Complex and the resulting surge shall be

accommodated through the turbines designed for such contingency, sluicing of

water through the power station and New Bong Escape duly synchronized with

the water flow and Complex operations or other arrangement for quick water

disposal.

1.4 Frequency, Power Factor, Voltage Limits and Droop Settings

(a) The Complex shall operate at 100% load with a power factor in the range 0.8

lagging to 0.9 leading; which range shall not be exceeded.

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(b) The Complex shall operate within the range ± 10 % on the 132 kV high voltage

system which range shall not be exceeded.

(c) The Complex shall operate within the frequency range as per NTDC Grid Code

2005 which range shall not be exceeded.

(d) The Complex shall be subject to tripping if frequency and/or voltage fluctuations

outside the ranges stated in 1.4(b) and 1.4 (c) occur.

(e) The Unit governor droop is adjustable in the range 0 % to 10 %.

(f) The automatic voltage regulator setting is adjustable in the range of ±10 % to

accommodate the fluctuations in rated voltage.

1.5 General

The Company shall advise the Power Purchaser of any temporary operating constraints

and limits which may, from time to time, apply to the Complex, including the minimum

and maximum operating range for each turbine generating unit based on water

availability of between 64.73 m3/s (2285.62 cusecs) and 253 m

3/s ( 8933.43cusecs).

2. Design Maintenance Limits

(a) Each unit will have Scheduled Outage hours in each Agreement Year as provided

in Schedule 11. Scheduled Outages include the Maintenance Outages of 145

hours for each Unit in each Agreement Year.

(b) Scheduled Outages continue on a one year cycle which must be maintained.

Major scheduled maintenance may be required during the Term and shall be

carried out, at the option of the Company, at any time after the 6th

year of

operations. Such major maintenance shall require 480 additional hours for each

Unit.

(c) The scheduling of maintenance inspections will be compatible with regulatory

requirements. All regulatory inspections shall be carried out during Scheduled

Outages. Subject to regulatory requirements, the timing of Scheduled Outages

shall be within a range 9 months to 15 months from the start of the previous

Scheduled Outage.

(d) Scheduled annual maintenance shall be carried out in the Maintenance Months to

minimize the impact on the Complex energy generation.

3. Prudent Utility Practice

Notwithstanding anything to the contrary, the Company shall operate and maintain the

Complex in accordance with Prudent Utility Practices.