Hysteresis loss: When a ferromagnetic core is magnetised by an alternating field, the magnetic domains are repeatedly reoriented. Domain-wall motion against internal friction makes $B$ lag behind $H$, and the work done in taking the material round the B–H loop is dissipated as heat. By Steinmetz's law

$P_h = k_h\, f\, B_m^{1.6}\ \text{(W/m}^3\text{)}$

It is reduced by using silicon steel or grain-oriented steel, which has a narrow loop.

Eddy current loss: The alternating flux induces emfs in the core itself, which drive circulating currents in planes perpendicular to the flux and cause $I^2R$ heating:

$P_e = k_e\, f^2\, B_m^2\, t^2\ \text{(W/m}^3\text{)}$

where $t$ is the lamination thickness. It is reduced by laminating the core (insulated thin sheets) and using high-resistivity steel.

Hysteresis loop on AC excitation: Let $H = H_m\sin\omega t$. Because of domain-wall friction, $B$ is a multi-valued function of $H$, so over one cycle $0\le\omega t\le 2\pi$ the point $(H,B)$ traces a closed loop:

• As $H$ rises from $0$ to $+H_m$, $B$ rises to $+B_m$ (saturation tip).
• As $H$ falls to $0$, $B$ falls only to the residual flux density (retentivity) $+B_r$; $B$ becomes zero only at $H=-H_c$, the coercivity.
• As $H$ goes on to $-H_m$, $B$ reaches $-B_m$; on the return to $0$ it is $-B_r$, and it becomes zero at $H=+H_c$, closing the loop.

A narrow loop (soft iron, silicon steel) means low loss; a wide loop (hard steel) means high loss but good permanent-magnet behaviour.

Energy stored and returned per cycle (per unit volume): For a change $dB$ the energy absorbed from the source is $dw = H\,dB$.

Rising half ($-B_m \to +B_m$, i.e. $B$ increasing): the energy supplied is the area between the ascending (upper-in-$H$) branch and the $B$ axis,

$W_{st} = \int_{-B_m}^{+B_m} H_{asc}\, dB$

Falling half ($+B_m \to -B_m$, $B$ decreasing): the energy given back is

$W_{ret} = \left|\int_{+B_m}^{-B_m} H_{desc}\, dB\right| = \int_{-B_m}^{+B_m} H_{desc}\, dB$

where, at any given $B$, $|H_{asc}|\ge|H_{desc}|$ in the sense $H_{asc}-H_{desc}>0$ (the field needed to raise $B$ exceeds the field at which it falls back). Hence $W_{st} > W_{ret}$: the core returns less energy than it receives. The net energy absorbed per cycle is

$W_h = W_{st} - W_{ret} = \oint H\,dB = \text{area of the B–H loop}\quad(\text{J/m}^3\text{ per cycle})$

This difference is not recovered; it appears as heat in the core. The hysteresis power loss for core volume $V$ is therefore

$P_h = f\, V \oint H\,dB \ \text{(W)}$

which, for Steinmetz's law, is $k_h f B_m^{1.6} V$.

Disconnecting Switch (DS) and its Operation

A disconnecting switch (DS), also called an isolator or isolating switch, is an off-load switching device used in substations and switchyards to isolate a circuit or equipment (circuit breaker, transformer, busbar, line) from the live system for maintenance, repair or inspection. It is a mechanical switch that provides a visible air gap in the circuit, so that the isolation is clearly seen by the operating personnel and safety is ensured.

Key features:

• It is designed to make and break circuits only when no current (or negligible current) is flowing — it has no arc-quenching arrangement like a circuit breaker.
• It is always operated after the associated circuit breaker has been opened, and closed before the circuit breaker is closed.
• It carries normal load current and short-circuit (fault) current continuously without damage, but cannot interrupt them.
• Interlocks (mechanical/electrical) are provided so that the DS cannot be opened while the breaker is closed.

Operation: The DS consists of fixed and moving contact blades mounted on insulators, operated manually (hand crank/lever) or by a motor mechanism. When the operating handle is turned, the moving blade rotates or slides and separates from the fixed contact, creating an air gap. The blade is positively latched in both the closed and open positions. Since the circuit breaker has already cleared the current, no arc is drawn at the contacts during opening. In motorised versions, the motor drive is controlled from the control room, with limit switches stopping the blade at the correct open/closed position.

---

Difference between DS with and without Earth Switch

---

Differential Protection System

Principle: Differential protection works on the Merz–Price circulating current principle, based on Kirchhoff's current law. The currents entering and leaving the protected zone are compared. Under normal or external-fault conditions these currents are equal, so their difference (spill) is zero and the relay does not operate. For a fault inside the protected zone, the currents differ, a differential current flows through the relay operating coil, and the relay trips the circuit breakers on all sides of the zone.

For a step-up power transformer:

Let the primary (generator side) current be $I_1$ and the secondary (line side) current be $I_2$. The CTs on both sides are chosen so that their secondary currents are equal for full-load through-current:

$\frac{I_1}{I_2} = \frac{N_2}{N_1} = \frac{V_2}{V_1} = \text{transformer turns ratio}$

CT ratio on primary side $= \dfrac{I_1}{1}$ A and on secondary side $= \dfrac{I_2}{1}$ A, so that both CT secondaries give the same current (say 1 A or 5 A) at rated load. Then:

$I_{\text{relay}} = I_{1}' - I_{2}'$

• Normal / external fault: $I_1' = I_2' \Rightarrow I_{\text{relay}} = 0$ → relay restrained, no trip.
• Internal fault: $I_1' \neq I_2' \Rightarrow I_{\text{relay}} = I_1' - I_2'$ (large) → relay operates and trips both HV and LV breakers.

Schematic diagram:

        Generator / Source
              |
              |  I1
              |
        +-----+-----+
        |  CT (HV)  |  ---> to relay restraint/operating coil
        +-----+-----+
              |
        +-----+-----+
        |  CB (HV)  |  <--- Trip signal from relay
        +-----+-----+
              |
        +-----+-----+
        |  Power    |
        | Transformer|
        |  (Step-up) |
        +-----+-----+
              |
        +-----+-----+
        |  CB (LV)  |  <--- Trip signal from relay
        +-----+-----+
              |
        |  CT (LV)  |  ---> to relay restraint/operating coil
        +-----+-----+
              |
           To Line / Load
              |
        I2

        Differential Relay (87T):
        I1' ---> [ Restraint Coil ] <--- I2'
                     |
              [ Operating Coil ] ---> Trip both CBs
                     |
                  (I1' - I2')

Working:

1. The CTs on the HV and LV sides are connected in a circulating current arrangement so that their secondary currents oppose each other in the relay circuit.
2. Under healthy conditions, the secondary currents balance and only a small magnetising/spill current flows in the operating coil — the relay remains stable.
3. When a fault occurs inside the transformer zone (winding fault, bushing fault, internal short circuit), the balance is disturbed. The sum of currents entering the zone is no longer equal to the current leaving it, so a large differential current flows through the operating coil.
4. The relay (type 87T) senses this differential current, and if it exceeds the setting, it energises the trip circuit, opening the HV and LV circuit breakers simultaneously, thus isolating the faulty transformer from both sides.

Additional features used in practice:

• Percentage bias / restraint to prevent maloperation due to CT errors, tap-changing, and magnetising inrush.
• Harmonic restraint (2nd harmonic) to avoid tripping on magnetising inrush current when the transformer is energised.
• High-set instantaneous element for severe internal faults.

Thus differential protection gives fast, selective and reliable protection to the step-up transformer, covering faults within its zone only.

Fire Fighting Techniques and Equipments for Electricity Fire Hazards; Earthing and Shielding Techniques

1. Fire Fighting Techniques and Equipments for Electricity Fire Hazards (5 marks)

Nature of electrical fire: Electrical fires are Class C fires (energized electrical equipment) involving live conductors, transformers, switchgear, cables and motors. The extinguishing agent must be non-conducting (dielectric) and must not leave residue that damages equipment. Water and foam must never be used on live equipment — they conduct electricity and cause electrocution.

Fire fighting techniques

1. De-energization (first and most important step): Switch off the main supply / trip the breaker before fighting the fire. This converts the electrical fire into an ordinary Class A/B fire and allows the use of water.
2. Isolation and confinement: Close doors, shut off ventilation/dampers to cut oxygen supply and prevent spread to adjacent panels or cable galleries.
3. Cooling: Apply clean agent or CO₂ to remove heat from the burning material.
4. Smothering / oxygen displacement: CO₂ or clean agents displace oxygen at the seat of fire without conducting current.
5. Use of fixed systems: For large installations (transformers, cable tunnels, control rooms), automatic systems operate on detection by smoke/heat/UV-IR detectors.
6. Evacuation and alarm: Raise alarm, evacuate personnel, inform fire brigade; fight fire only from the windward side with a safe escape route.
7. Never open a burning equipment enclosure suddenly — inrush of air can cause flashover.

Fire fighting equipments

Key precautions: maintain safe distance (CO₂: minimum 1 m for 4.5 kg, more for larger), do not touch the metal horn of CO₂ extinguisher (cold burn), use only approved dielectric agents, and keep extinguishers inspected and refilled as per IS/Nepal standards.

---

2. Earthing and Shielding Techniques in Electrical System (5 marks)

Earthing (Grounding)

Definition: Earthing is the intentional connection of the non-current-carrying metallic parts of electrical equipment (and the neutral point of the system) to the general mass of earth through a low-resistance path.

Purpose:

• Provides a low-resistance path for fault current so that protective devices (fuse, MCB, ELCB/RCCB) operate quickly.
• Limits touch and step potential to safe values, protecting personnel from electric shock.
• Protects equipment from lightning surges and static charge.
• Maintains system neutral at earth potential and ensures proper operation of protective relays.

Types of earthing:

1. Pipe earthing: A galvanized iron pipe (38–50 mm dia, 2–3 m long) buried vertically; charcoal and salt around it to reduce resistance. Used for domestic and small installations.
2. Plate earthing: Copper or GI plate (60 cm × 60 cm × 3 mm for copper) buried vertically at about 1.5 m depth with alternate layers of charcoal and salt. Used for substations and large installations.
3. Rod earthing: Copper or GI rod driven into ground; simple and cheap, used where soil resistivity is low.
4. Strip / strip-and-pipe earthing: Horizontal strip buried in trench; used where soil is rocky or shallow.
5. System earthing: Solid, resistance, reactance or resonant earthing of the neutral point of generators/transformers.

Earthing resistance: Should be as low as possible — generally ≤ 1 Ω for substations, ≤ 5 Ω for domestic installations (as per IS 3043 / NBC). Measured by fall-of-potential or earth tester (megger).

Earthing electrode materials: Copper (best conductivity, costly), GI (cheaper, used widely in Nepal), graphite, and chemical earthing compounds (bentonite, marconite) to maintain moisture and low resistance.

Shielding Techniques

Definition: Shielding is the technique of enclosing electrical conductors, equipment or cables with a conducting or magnetic barrier to prevent interference, electric field, or lightning surge from reaching the protected object.

Types and applications:

1. Electrostatic shielding: A conducting enclosure (Faraday cage) connected to earth prevents external electric fields from inducing voltage in the enclosed conductor. Used in instrumentation cables, signal cables and control cables.
2. Electromagnetic shielding: Conducting or magnetic material (copper, aluminium, mu-metal) surrounds the conductor to attenuate electromagnetic interference (EMI). Used in communication cables, coaxial cables and data cables.
3. Cable shielding: Metallic sheath/braid over insulated conductors to:
   • Confine the electric field within the cable.
   • Provide a return path for capacitive/induced currents.
   • Protect against mechanical damage and moisture.
   • Reduce electromagnetic interference with neighbouring circuits.
4. Lightning / surge shielding: Overhead earth wire (shield wire) above transmission lines, and surge arresters, divert lightning strokes to earth, protecting line insulators and equipment.
5. Magnetic shielding: High-permeability material (mu-metal) used around sensitive instruments to divert magnetic flux.
6. Shielding of substations: Earthing mat, shield wires and surge diverters protect substation equipment from direct and induced lightning surges.

Difference between earthing and shielding:

Conclusion: Proper earthing ensures safety of personnel and equipment by providing a low-resistance fault path, while shielding prevents external electrical and magnetic disturbances from affecting the system. Together they form the backbone of electrical safety in power systems.

Transients in Electrical Circuits

Definition: A transient is the temporary, time-varying condition that occurs in a circuit immediately after a sudden change — such as switching on/off a source, opening or closing a switch, or a sudden change in load — before the circuit settles into its new steady state. During this interval the voltages and currents change from their old steady values to new steady values, and the energy stored in inductors (magnetic field) and capacitors (electric field) cannot change instantaneously. The transient dies out after a time governed by the circuit time constant, and the circuit then reaches steady state.

Key points:

• Transients occur only in circuits containing energy-storage elements (L or C), since resistive circuits respond instantaneously.
• The inductor current $i_L$ and capacitor voltage $v_C$ cannot change abruptly: $i_L(0^+)=i_L(0^-)$ and $v_C(0^+)=v_C(0^-)$.
• The complete response = natural (transient) response + forced (steady-state) response.

---

1. Natural Response

The natural response is the behaviour of the circuit due to the initial energy stored in L or C, with no external source (source removed). It is the solution of the source-free (homogeneous) equation and always decays exponentially.

RC circuit (source-free): A charged capacitor $V_0$ discharges through $R$.

$v_C(t) = V_0 e^{-t/\tau}, \qquad i(t) = -\frac{V_0}{R} e^{-t/\tau}, \qquad \tau = RC$

RL circuit (source-free): An inductor carrying $I_0$ discharges through $R$.

$i(t) = I_0 e^{-t/\tau}, \qquad v_L(t) = -I_0 R\, e^{-t/\tau}, \qquad \tau = \frac{L}{R}$

Here $\tau$ is the time constant. After one $\tau$ the quantity falls to $36.8\%$ of its initial value; after $5\tau$ the transient is practically over.

---

2. Step Response

The step response is the response when a DC source (a step voltage/current) is suddenly applied to an initially relaxed circuit. The complete response is:

$x(t) = x(\infty) + \big[x(0^+) - x(\infty)\big] e^{-t/\tau}$

where $x(\infty)$ is the final steady-state value.

RC circuit (step voltage $V_s$ applied):

$v_C(t) = V_s\left(1 - e^{-t/\tau}\right), \qquad i(t) = \frac{V_s}{R} e^{-t/\tau}, \qquad \tau = RC$

The capacitor voltage rises exponentially from 0 to $V_s$; the current starts at $V_s/R$ and decays to zero. The capacitor finally behaves as an open circuit.

RL circuit (step voltage $V_s$ applied):

$i(t) = \frac{V_s}{R}\left(1 - e^{-t/\tau}\right), \qquad v_L(t) = V_s e^{-t/\tau}, \qquad \tau = \frac{L}{R}$

The inductor current rises exponentially from 0 to $V_s/R$; the inductor voltage starts at $V_s$ and decays to zero. The inductor finally behaves as a short circuit.

---

Summary Table

Conclusion: The transient in an RL or RC circuit is the exponential transition between two steady states. Its rate is fixed by the time constant $\tau$; the natural response describes decay of stored energy, while the step response describes the growth of voltage/current when a DC source is switched in.

Auxiliary equipment in a hydropower station are all those equipment and systems, other than the main generating units (turbine, generator, transformer), that are needed for the safe, reliable and efficient operation, control, protection and maintenance of the plant. They are broadly classified as follows:

1. Electrical auxiliaries

• Station service (unit) transformers and auxiliary power supply (AC/DC)
• DC battery bank, battery chargers and UPS
• Excitation system, AVR and synchronising equipment
• Switchgear: circuit breakers, isolators, CTs, PTs, surge arresters, busbars
• Protection relays, control, metering, SCADA/telemetry and communication systems
• Station and emergency lighting, earthing and lightning protection

2. Mechanical auxiliaries

• Governing system (governor, servomotor, oil pressure unit)
• Lubricating oil system (oil pumps, coolers, filters, sump tanks)
• Cooling water system (for generator air coolers, thrust and guide bearings, transformer oil coolers)
• Compressed air system (for air circuit breakers, brake air, pneumatic tools)
• Dewatering and drainage system (sump pumps, leakage pumps)
• Fire fighting system (hydrant, sprinkler, CO₂/foam, fire detection)
• Ventilation and air-conditioning of the powerhouse
• Overhead/travelling crane, hoists and gantry crane
• Turbine inlet valve (spherical/butterfly valve) and its control

3. Hydraulic auxiliaries

• Penstock, surge tank, trash rack and trash-rack cleaning machine
• Head race and tail race, draft tube gate, intake gate and their hoists
• Water level and flow measuring instruments

4. Miscellaneous auxiliaries

• Workshop, stores, staff quarters, access road, drainage and sewage, security and safety equipment

---

Explanation of one type — Governing (governor) system

The governing system is the most important mechanical auxiliary of a hydropower station. Its function is to keep the turbine speed constant (i.e. frequency constant at 50 Hz) irrespective of the load on the generator, and to start, stop and protect the unit.

Main components:

1. Speed sensing element — a permanent magnet generator (PMG) or flyball/tacho-generator mounted on the shaft, which gives a voltage proportional to speed.
2. Governor controller (cabinet) — electronic/PLC unit that compares the actual speed with the reference speed and produces a control signal.
3. Electro-hydraulic servo valve — converts the electrical signal into an oil pressure signal.
4. Oil pressure unit (OPU) — oil sump, screw/gear pumps, accumulator (air vessel), relief valve and piping, which supplies high-pressure oil (typically 40–63 bar).
5. Servomotor — a piston-cylinder unit that moves the distributor (wicket gates) or needle of the turbine.
6. Feedback (follow-up) mechanism — returns the actual gate position to the controller to stop hunting.

Working: When the load on the generator increases, the speed falls; the speed sensing element senses this drop, the controller sends a signal to the servo valve, high-pressure oil enters the servomotor and opens the wicket gates, admitting more water to the turbine. The speed rises back to the rated value. When the load decreases, the reverse action closes the gates. Thus the input water power is continuously matched to the output electrical load. In case of a sudden full load rejection, the governor closes the gates quickly (with a temporary speed rise limited by the temporary speed rise and pressure rise limits) to prevent runaway speed.

Types: mechanical/hydraulic governor (older), electro-mechanical, and modern electronic (PID) governor with PLC control. Electronic governors are now standard because of fast response, easy tuning of PID constants and remote/SCADA operation.

Necessity: Without a governor the frequency would vary with load, the turbine could reach runaway speed on load rejection, and parallel operation with other units/grid would be impossible. Hence the governing system is essential for stability, quality of power supply and protection of the machine.

Speed Control of a Shunt DC Motor

1. Operating Principle

In a shunt DC motor, the field winding is connected in parallel with the armature across the same supply. The motor works on the principle that when a current-carrying conductor is placed in a magnetic field, it experiences a force (F = BIl), producing torque that rotates the armature. The back emf developed in the armature is:

$E_b = \frac{P\phi ZN}{60A} = V - I_a R_a$

Rearranging for speed:

$N = \frac{60A(V - I_a R_a)}{P\phi Z} = K \frac{E_b}{\phi} = K \frac{V - I_a R_a}{\phi}$

where K is a constant for the machine. Hence, speed depends on (i) supply voltage V, (ii) armature circuit resistance R_a, and (iii) field flux φ. These three quantities form the basis of all speed control methods.

2. Speed Control Below Rated Speed

Method: Armature resistance control (armature rheostat)

A variable resistance R_ext is inserted in series with the armature. Then:

$N = K \frac{V - I_a (R_a + R_{ext})}{\phi}$

Since φ is unchanged (shunt field is independent of armature), the numerator decreases, so speed falls below the rated value. Speed can be varied from rated speed down to a very low value by increasing R_ext.

Drawbacks: Large I²R loss in the rheostat (poor efficiency), speed varies with load (poor regulation), and only speeds below rated speed are obtainable. Used for cranes, hoists and intermittent low-speed duty.

3. Speed Control Above Rated Speed

Method: Field flux control (field rheostat)

A variable resistance R_fc is inserted in series with the shunt field winding. This reduces field current:

$I_f = \frac{V}{R_f + R_{fc}} \quad \Rightarrow \quad \phi \propto I_f \text{ decreases}$

Since N ∝ 1/φ, reducing the flux raises the speed above rated speed. This is the standard method for speeds above rated value, and it is very efficient because field current is small (only a small power loss in the field rheostat).

Limitation: Speed can be raised only up to about 1.5–2 times rated speed; beyond this, flux becomes very weak, armature reaction distorts the field, commutation becomes poor (sparking), and the motor may become unstable (runaway risk if field opens).

4. Other Supporting Methods

• Voltage control (Ward-Leonard system): Supply voltage to the armature is varied by a motor-generator set. Speed varies smoothly from zero to rated (below base speed) and, with field weakening, above base speed. Gives wide, smooth, lossless control in both directions — used in rolling mills and mine winders.
• Solid-state (thyristor/chopper) control: Armature voltage is varied electronically; combines the advantages of voltage control without a rotating M-G set.

5. Summary

Thus, speed below rated value is obtained by adding armature resistance (or reducing armature voltage), while speed above rated value is obtained by reducing the field flux.

Major problems in land acquisition for development projects in Nepal (2 marks)

1. Lengthy and complex legal procedure — The Land Acquisition Act, 2034 (1977) requires repeated notices, objection hearings, claim verification and compensation fixation, so acquisition often takes years and delays projects.
2. Inadequate and delayed compensation — Compensation is frequently fixed below market value, is not inflation-adjusted, and is paid late, causing hardship and resistance from affected families.
3. Unclear land ownership and records — Dual ownership (mohi–landlord), unregistered guthi and ailani (public) land, squatters and outdated cadastral maps create disputes over who is entitled to compensation.
4. Resistance, protest and politicisation — Poor consultation, distrust of the process, political interference and pressure groups often stall acquisition, while middlemen and speculation raise land prices abnormally.
5. Weak resettlement and rehabilitation (R&R) — Compensation is treated as a one-time cash payment; livelihood restoration, employment and rehabilitation of displaced and vulnerable groups are neglected.

Appropriate suggestions to solve the problems (3 marks)

1. Amend and modernise the legal framework — Update the Land Acquisition Act to make procedures time-bound and transparent, and enact a separate Resettlement and Rehabilitation Act with clear entitlements.
2. Strengthen land records — Complete digital cadastral surveying, resolve dual ownership and guthi/ailani land issues, and maintain an up-to-date land information system (GIS-based).
3. Ensure fair, market-based and timely compensation — Assess value through independent valuers, adjust for inflation, pay before taking possession, and offer options such as land-for-land or project equity/shares.
4. Adopt participatory and transparent planning — Hold public hearings and consultations with affected communities, disclose project alignment and compensation norms early, and set up an accessible grievance-redress mechanism.
5. Minimise displacement through better planning — Select alignments/designs that avoid productive and settlement land, use public land where possible, and apply land pooling and readjustment (as practised in Kathmandu Valley).
6. Create a land bank — Government should pre-acquire and reserve land in advance for future infrastructure, reducing delay and speculative price rise.
7. Build institutional capacity — Train valuation and land-acquisition staff, create a dedicated acquisition cell in each project, and coordinate among the Ministry of Land Management, local governments and project offices.
8. Control speculation and political interference — Enforce land-use zoning and land-ceiling provisions, and secure political consensus so that acquisition is guided by law and public interest rather than pressure.

Necessity of Nepal Electricity Authority (NEA) Restructuring in the Federal Context

Nepal's transition to a federal democratic republic under the Constitution of 2072 BS created three tiers of government — federal, provincial and local — each with defined constitutional responsibilities. The Nepal Electricity Authority, established in 2042 BS as a single, centralised, vertically integrated monopoly, no longer fits this structure. Its restructuring has therefore become necessary for the following reasons:

1. Constitutional and legal alignment. Schedule 5 (federal), Schedule 6 (provincial) and Schedule 7 (concurrent) of the Constitution assign electricity-related functions across all three tiers. The Local Government Operation Act, 2074 BS gives local governments responsibility for small hydropower, rural electrification and distribution within their areas. Without restructuring, NEA remains a federal body discharging functions that constitutionally belong to provinces and local units, creating jurisdictional conflict.

2. Decentralised service delivery. A single central authority cannot efficiently plan, operate and maintain distribution networks spread across 7 provinces, 77 districts and 753 local units. Restructuring through provincial subsidiaries or provincial distribution companies brings decision-making closer to consumers, shortens response time for outages and new connections, and improves accountability.

3. Balanced regional development. Nepal's hydropower potential is concentrated in provinces like Gandaki and Karnali while demand is concentrated in Bagmati and Terai. Restructuring enables each province to develop its own generation, transmission and distribution capacity, retain local benefits such as royalties and employment, and reduce inter-provincial inequity.

4. Financial viability and autonomy. NEA has long carried large accumulated losses, high technical and non-technical losses (around 15–17 per cent in recent years), and heavy dependence on the centre for investment. Restructuring into separate generation, transmission, distribution and trading entities allows cost-reflective tariffs, ring-fenced accounts, performance benchmarking and access to provincial and private capital.

5. Private sector participation and competition. The Electricity Act and Electricity Regulatory Commission provide for a competitive market. Restructuring separates the regulatory, policy-making and operational roles, prevents NEA from being both player and referee, and creates room for independent power producers, community electricity users' organisations and provincial-level investors.

6. Efficient federal–provincial coordination. Restructuring defines clear ownership of assets, revenue-sharing arrangements and inter-governmental transfer mechanisms, reducing duplication of effort and disputes over transmission lines, substations and electrification projects.

7. Consumer welfare and accountability. Provincial and local entities can be held accountable through provincial assemblies and local councils, tariffs can reflect local costs, and subsidy targeting (such as for irrigation, community and low-income consumers) becomes more effective.

Conclusion. Restructuring of NEA is not merely an administrative reform but a constitutional necessity. It should proceed through a phased model — a federal holding company for national transmission and inter-provincial generation, provincial distribution companies, and local-level participation in rural electrification — so that federalism delivers reliable, affordable and equitable electricity to all citizens.

Analysis of the Present Investment Model for Hydroelectricity Development in Nepal

Nepal has an economically viable hydropower potential of about 43,000 MW (theoretical 83,000 MW), but installed capacity is only around 3,000 MW. The present investment model is a mixed model, dominated by the private sector under a liberalised policy regime. Its main features, strengths and weaknesses are analysed below.

1. Dominance of the private sector (IPPs) Since the Electricity Act, 2049 (1992) and the Hydropower Development Policy, 2051 (1992), later revised in 2058 (2001), the state monopoly of the Nepal Electricity Authority (NEA) was ended. Independent Power Producers (IPPs) now own roughly 80–85% of installed capacity. Investment is mobilised through:

• Equity: promoter contribution (about 30–40%), often from banks, trading houses, remittance earners and non-resident Nepalis.
• Debt: bank loans (about 60–70%), mainly from commercial banks, Employees Provident Fund, Citizen Investment Trust and Nepal Rastra Bank's refinance window, plus foreign debt from IFC, ADB, EIB and Chinese banks.

2. Build-Own-Operate-Transfer (BOOT) / BOO concessions The state grants survey licences, generation licences (up to 25 years, extendable) and a 30-year PPA with NEA. Ownership reverts to the government after the licence period in BOOT projects. This shifts construction and operating risk to the private developer while the state provides the resource and the market.

3. Guaranteed market and tariff structure NEA is the single buyer. PPAs are on a take-or-pay basis with a flat energy rate (Rs/kWh) plus capacity payment for dry-season energy. Tariffs are escalated at 3% per year for five years. This guarantees revenue but also creates "take-or-pay" liabilities — NEA must pay even when it cannot sell the power (e.g. during the monsoon or load-shedding-free surplus periods), leading to a growing financial burden on NEA.

4. Public/state investment

• NEA-owned projects (Kulekhani, Kaligandaki A, Middle Marsyangdi, Chameliya, Upper Tamakoshi) financed by government equity, domestic borrowing and concessional foreign loans.
• Joint-venture and public-enterprise models — e.g. Chilime Hydropower Company's subsidiary/associate model, where a promoter company floats shares to the public and local people.
• Public-private partnership (PPP) and Build-Own-Operate (BOO) for larger projects such as Upper Arun, Dudh Koshi and Tamor.

5. Domestic capital market mobilisation Hydropower is now the largest sector on the NEPSE, with over Rs 300 billion raised through IPOs, FPOs, debentures and right shares. This has democratised ownership and channelled remittance and bank deposits into productive use. However, it has also created over-subscription and speculative bubbles, and many projects are over-leveraged.

6. Foreign direct investment (FDI) FDI inflows have been modest and concentrated in a few large projects. Investors are discouraged by:

• PPA delays and NEA's weak financial position (large accumulated losses, high receivables).
• Land acquisition, resettlement and local obstruction (e.g. demands for free electricity, shares and compensation).
• Policy instability, licensing disputes and delays in transmission line construction (e.g. the Kathmandu–Bhairahawa and Butwal–Gorakhpur lines).
• Currency and repatriation risks.

7. Transmission and evacuation constraints Investment has concentrated on generation while transmission and distribution lag behind, causing curtailment and stranded capacity. The NEA's single-buyer monopoly and lack of a competitive wholesale market further distort the model.

8. Cross-border electricity trade The present model increasingly relies on export to India and Bangladesh through the Nepal–India Power Trade Agreement (2014) and the BBIN framework. This opens a new revenue stream but makes Nepal dependent on Indian market access and transmission corridors.

Conclusion The present investment model — private-led, PPA-guaranteed, bank-financed and increasingly IPO-driven — has rapidly expanded capacity but suffers from structural weaknesses: NEA's financial unsustainability, transmission bottlenecks, policy inconsistency, weak local ownership benefits and over-dependence on the Indian market. A reformed model should emphasise transmission investment, a financially viable single buyer or competitive market, clear risk-sharing in PPAs, community equity participation and diversified export markets to make hydropower a genuinely sustainable driver of the economy.

Activities involved in the formulation of a plan

Plan formulation is the process of preparing a systematic framework of objectives, policies, programmes and resources to achieve desired development goals. The main activities involved are:

1. Identification of needs and problems — Studying the existing situation, collecting data and identifying the needs, problems and potentials of the area or sector.

2. Setting of objectives and goals — Defining clear, measurable and time-bound objectives (short-term, medium-term and long-term) that the plan intends to achieve.

3. Determining priorities — Selecting and ranking the objectives and programmes on the basis of urgency, resource availability and national importance.

4. Formulation of policies and strategies — Framing the guiding policies, strategies and approaches through which the objectives will be attained.

5. Preparation of programmes and projects — Converting objectives into concrete programmes and projects with defined activities, targets and implementing agencies.

6. Estimation of resources and budgeting — Assessing the required financial, physical and human resources and preparing the budget, including internal and foreign sources.

7. Fixing of targets and time schedule — Assigning quantitative targets and a time frame for each programme and project.

8. Consultation and approval — Discussing the draft plan with concerned ministries, agencies and stakeholders, and getting it approved by the National Planning Commission and the Council of Ministers.

9. Monitoring and evaluation framework — Providing arrangements for implementation, monitoring, evaluation and feedback so that the plan can be revised as required.

Public Private Partnership (PPP) as an Approach to Development in Developing Countries

Concept of PPP (3 marks)

Public Private Partnership (PPP) is a long-term contractual arrangement between a government/public entity and a private sector partner for the design, financing, construction, operation and/or maintenance of public infrastructure or delivery of public services. In a PPP, the public sector retains ownership, regulatory control and responsibility for public interest, while the private partner brings capital, technical expertise, managerial efficiency and, in many models, bears a share of the risks. The costs are recovered either through user charges (tolls, tariffs, fees), through government payments, or a combination of both.

PPP is promoted as a development approach in developing countries because:

1. Resource gap filling — governments face fiscal constraints; PPP mobilises private capital for large infrastructure such as roads, hydropower, water supply, airports and hospitals.
2. Efficiency and innovation — private management typically delivers services at lower cost and better quality, and introduces new technology.
3. Risk sharing — risks are allocated to the party best able to manage them (construction risk to the contractor, demand risk to the operator, political/regulatory risk to the government).
4. Value for money — whole-life costing of design, construction and operation reduces total cost over the project cycle.
5. Capacity and technology transfer — local institutions learn modern practices, and revenue is generated without immediate fiscal outlay.

Common PPP models include BOT (Build–Operate–Transfer), BOOT, DBFO (Design–Build–Finance–Operate), and management or lease contracts. In Nepal, examples are the BOT model applied to hydropower projects (e.g., Upper Tamakoshi structured with public–private–community participation), the Kathmandu–Bhaktapur and Kathmandu–Kulekhani road projects, and private participation in solid waste management and water supply in some municipalities. In India, the Indira Gandhi International Airport and the Delhi–Gurgaon Expressway are well-known PPP cases.

Key Challenges of PPP (2 marks)

1. Weak legal, regulatory and institutional framework — many developing countries lack clear PPP policy, standard concession agreements and dispute-resolution mechanisms. In Nepal, the PPP policy framework remained incomplete for years, delaying projects.
2. Risk allocation and demand forecasting errors — traffic or revenue projections are often overestimated. The Delhi–Gurgaon Expressway faced heavy cost overruns and disputes over tolling, and many Indian airport/road PPPs required renegotiation.
3. Financing constraints and high cost of capital — private borrowing is costlier than sovereign borrowing; long-tenor local currency finance is scarce. Hydropower BOT projects in Nepal have suffered from delays in financial closure.
4. Land acquisition, resettlement and clearances — delays in land acquisition and environmental clearance are a major cause of time and cost overruns in South Asian PPPs.
5. Political instability and contract enforcement risk — changes in government, populist pressure on tariffs and weak enforcement discourage private investors. Nepal's political transition has repeatedly stalled PPP infrastructure.
6. Limited private sector capacity and transparency concerns — few domestic firms have the balance sheet for large PPPs, and lack of competitive bidding and transparency can lead to cronyism and inflated costs.
7. Affordability and equity issues — cost recovery through user charges may exclude the poor; tariff hikes are politically sensitive (e.g., water tariff disputes in Kathmandu).

Conclusion

PPP is a useful instrument to bridge the infrastructure and service delivery gap in developing countries, but its success depends on a clear legal framework, realistic risk sharing, competitive and transparent procurement, and stable political commitment. Without these, PPPs tend to shift from partnership to dispute.

Role of Independent Power Producers (IPPs) in Hydroelectricity Development in Nepal — 5 marks

1. Supplementing public investment. The Nepal Electricity Authority (NEA) alone cannot fund the large capital required for hydropower. IPPs mobilise private and foreign capital, adding thousands of megawatts to the grid that the government could not have financed alone. Over 100 IPPs are now in operation, contributing the bulk of Nepal's installed capacity.

2. Utilising economically viable small and medium projects. IPPs have concentrated on run-of-river projects in the 1–100 MW range, which need less capital, shorter construction periods and simpler technology — sites that were neglected when only large projects were pursued.

3. Technology and management transfer. Private developers bring modern turbine, generator and SCADA technology, international engineering practices and competitive management, raising the overall efficiency and reliability of the sector.

4. Employment, revenue and local development. IPPs create construction and operation jobs, pay corporate tax, royalties and local development fees to the government, and support rural electrification, roads and schools in project areas — contributing to the national economy and to SDG 7 (affordable, clean energy).

5. Energy trade and energy security. IPP-generated surplus power is exported to India and proposed for Bangladesh, earning foreign currency. Domestic supply has shifted from load-shedding to near surplus, improving industrial productivity and reducing dependence on imported fossil fuel.

Limitations. IPPs face problems of PPA delays, transmission constraints, financial closure difficulties, and criticism over royalty evasion and insufficient local benefit sharing. Strong regulation by the Electricity Regulatory Commission is therefore needed.

Conclusion. IPPs have become the backbone of Nepal's hydropower expansion, but their contribution will be sustainable only with transparent policy, reliable transmission infrastructure and fair benefit sharing.

Corruption in Nepal: Causes, Consequences and Control Efforts

Introduction Corruption is the abuse of entrusted public power for private gain — bribery, nepotism, favouritism, embezzlement, kickbacks in procurement and "commission" in service delivery. In Nepal it has become systemic rather than incidental, and Transparency International's Corruption Perceptions Index has consistently placed the country in the lower-middle band of the global ranking. For an engineer in public service, corruption is not an abstract issue: it appears directly in tender fixing, cost escalation of infrastructure, substandard construction and the leakage of development budgets. This answer discusses its causes, its consequences for national development, and the efforts made to control it.

Causes of Corruption

Institutional and legal causes

1. Weak enforcement: laws exist but investigation and prosecution are slow, and convictions are few.
2. Impunity and political protection: powerful persons are shielded; cases are withdrawn or left pending.
3. Low risk, high reward: the expected cost of corruption is far smaller than its benefit.
4. Bureaucratic complexity: excessive rules, discretionary powers and monopoly over decisions create rent-seeking opportunities.
5. Weak accountability institutions: audit, parliamentary oversight and local accountability remain weak.

Economic causes 6. Low and unequal remuneration: salaries that do not match the cost of living, combined with wide income inequality. 7. Scarcity and rationing: scarce jobs, land, licences, contracts and budgets invite bribes. 8. Big public spending: large infrastructure budgets with weak procurement systems attract kickbacks.

Social and political causes 9. Culture of gift-giving and favouritism: kinship, caste, party and "afno manche" (one's own people) networks. 10. Political instability and coalition politics: frequent changes weaken long-term accountability and encourage short-term extraction. 11. Moral decline and weak social sanction: corruption is often normalised and even admired as "smartness". 12. Weak citizen awareness and low demand for accountability.

Consequences for National Development

Economic consequences

1. Capital leakage: a large share of development funds is diverted, so projects cost more and deliver less.
2. Poor quality infrastructure: substandard roads, bridges, buildings and irrigation works fail early, causing repeated investment and loss of life.
3. Reduced investment: domestic and foreign investors avoid a corrupt environment; growth and employment suffer.
4. Fiscal loss: revenue leakage, tax evasion and misdirected subsidies shrink the resources available for health, education and social security.
5. Distorted priorities: projects are chosen for the size of the kickback, not for economic return.

Social consequences 6. Poor service delivery: citizens must pay bribes for services they are entitled to free, hitting the poor hardest. 7. Widening inequality: corruption transfers resources from the poor to the rich and politically connected. 8. Erosion of trust: loss of faith in the state, the bureaucracy and the judiciary. 9. Migration and brain drain: capable young people leave because merit is not rewarded. 10. Linkage with organised crime: smuggling, tax evasion and illegal extraction of sand, stone and timber.

Political consequences 11. Criminalisation of politics and the use of money and muscle power in elections. 12. Weakening of democracy, rule of law and the legitimacy of public institutions. 13. In sum, corruption acts as a hidden tax on development: it raises the cost of every unit of public investment and lowers its benefit.

Efforts Made to Combat Corruption

Constitutional and legal framework

1. Article 239 of the Constitution of Nepal provides for the Commission for the Investigation of Abuse of Authority (CIAA) as a constitutional anti-corruption body.
2. Prevention of Corruption Act, 2059 (2002) and its amendments define corruption offences and penalties.
3. Commission for the Investigation of Abuse of Authority Act, 2048; National Vigilance Centre; and the Commission on Investigation of Abuse of Authority's power to investigate and prosecute.
4. Right to Information Act, 2064 — a key transparency tool.
5. Public Procurement Act, 2063 and Regulations — competitive bidding, e-procurement and bid security.
6. Anti-Money Laundering Act, 2064; Asset (Money) Laundering Prevention; and the Financial Information Unit.
7. Good Governance (Management and Operation) Act, 2064 — citizen charter, service delivery standards.

Institutional mechanisms 8. CIAA — investigation and prosecution of abuse of authority; special courts and the Special Court. 9. National Vigilance Centre — preventive and awareness role. 10. Office of the Auditor General — annual audit and reporting to Parliament. 11. Public Accounts Committee of Parliament — oversight of audit reports. 12. National Human Rights Commission and other watchdogs; Commission for the Investigation of Abuse of Authority's hotline and complaint handling. 13. E-governance initiatives: e-procurement, online passport, national ID, digital payment of revenue and salaries — reducing face-to-face discretion.

Reform and preventive measures 14. Citizen charter and grievance-handling mechanisms in offices. 15. Right to information and proactive disclosure; social audit and public hearing at local level (mandatory under local government laws). 16. Public procurement reform: e-bidding, framework agreements, blacklisting of defaulting contractors. 17. Civil service reform: performance-based transfer, code of conduct, asset declaration by public officials. 18. Anti-corruption education and awareness campaigns; involvement of media, civil society and youth. 19. International cooperation: UN Convention against Corruption (UNCAC) ratification, mutual legal assistance, asset recovery.

Assessment of These Efforts

• Positive: constitutional status of CIAA, legal framework, e-governance and RTI have created real deterrents and some high-profile actions.
• Limitations: political interference in appointments and investigations; weak prosecution and conviction rate; resource and capacity constraints; delays in the judiciary; lack of protection for whistle-blowers; and the fact that prevention has lagged behind investigation.
• Corruption has also adapted — from cash bribes to benami assets, commission through subcontracting and inflated bills — so enforcement alone cannot keep pace.

Conclusion and Way Forward Corruption in Nepal is driven by a combination of weak institutions, impunity, low pay, scarcity and social acceptance, and it directly damages infrastructure quality, investment, equity and public trust. The existing legal and institutional framework is broadly adequate but weakly enforced. What is needed is: (i) strict and timely enforcement with credible punishment; (ii) reduction of discretionary power through simplification and digitalisation; (iii) transparent, e-procurement-based public contracting with strong audit follow-up; (iv) fair remuneration and merit-based career management; (v) strong whistle-blower protection; and (vi) sustained citizen awareness so that corruption loses social prestige. As a public engineer, the practical contribution lies in honest estimation, fair tendering, strict quality control and refusal of undue influence — integrity in one's own office is the first step in fighting corruption at the national level.

Strategic Management

Strategic management is the continuous process of formulating, implementing and evaluating cross-functional decisions that enable an organisation to achieve its long-term objectives. It involves environmental scanning (internal and external), strategy formulation (vision, mission, objectives, strategies), strategy implementation (resource allocation, structure, systems, leadership) and strategy evaluation and control (performance measurement, corrective action). In essence, it is the art and science of formulating, implementing and evaluating decisions that allow an organisation to achieve its stated goals by aligning its internal strengths with the external environment.

Major Problems in Implementing Strategic Management in State Owned Enterprises in Nepal

1. Political interference and instability: Frequent changes in government lead to changes in leadership (boards, managing directors) of SOEs. Long-term strategy is sacrificed for short-term political gains. Appointments are made on political affiliation rather than competence.

2. Lack of clear vision, mission and objectives: Many SOEs operate without a documented strategic plan. Even where plans exist, they are not cascaded down to departmental and individual levels.

3. Weak corporate governance: Board members often lack professional competence. Boards fail to provide strategic direction and instead get involved in day-to-day management. Accountability mechanisms are weak.

4. Resource constraints and financial indiscipline: Inadequate capital, poor revenue collection, mounting losses, overdependence on government subsidies and inability to raise funds from capital markets limit strategy implementation.

5. Bureaucratic and rigid organisational structure: Centralised decision-making, lengthy approval processes and resistance to change slow down strategy execution. There is little delegation and weak performance-based reward systems.

6. Inadequate performance measurement systems: Absence of balanced scorecards, key performance indicators (KPIs) and management information systems makes monitoring and evaluation of strategy ineffective.

7. Human resource issues: Lack of skilled manpower, poor training and development, low motivation, overstaffing in unskilled categories and shortage in technical/professional categories.

8. Trade union and employee resistance: Unions often oppose restructuring, automation and reform measures that are essential components of strategic change.

9. Weak monitoring and evaluation: Strategic plans are rarely reviewed periodically; there is no institutional mechanism for feedback and corrective action.

10. Corruption and lack of transparency: Procurement irregularities, leakage and rent-seeking divert resources away from strategic priorities.

Suggestions for Implementing Strategic Management in Nepal Electricity Authority (NEA)

1. Formulate a clear long-term strategic plan: Prepare a 10–15 year corporate strategy with a clear vision (e.g., reliable, affordable and sustainable electricity for all), measurable objectives (loss reduction, generation capacity addition, financial sustainability) and annual business plans linked to the national plan and SDG 7.

2. Strengthen corporate governance: Make the Board of Directors professionally competent and autonomous. Separate ownership (Ministry) from management. Adopt a code of conduct, audit committee and strict disclosure norms.

3. Reduce technical and non-technical losses: Set time-bound targets (e.g., reduce system loss to below 8%) through smart metering, feeder-wise energy accounting, GIS-based network mapping and strict action against electricity theft.

4. Improve financial management: Rationalise tariffs through the Electricity Regulatory Commission on a cost-reflective basis, improve revenue collection efficiency, reduce arrears of government and industrial consumers, and explore bond issuance and donor/PPP financing for capital projects.

5. Adopt performance-based management: Introduce KPIs, balanced scorecard, performance contracts between the Ministry and NEA, and link promotion and incentives to performance.

6. Develop human resources: Conduct skills gap analysis, provide technical training (especially in transmission, distribution automation and IT), and recruit competent professionals through transparent competition.

7. Promote clean and diversified energy: Fast-track hydropower and solar projects, encourage private sector participation through PPAs, and manage seasonal surplus/deficit through trade with India and Bangladesh.

8. Improve customer service: Adopt one-window service, online billing and payment, grievance-handling mechanisms and consumer awareness programmes.

9. Institutionalise monitoring and evaluation: Conduct periodic strategy review, internal audit and third-party evaluation, and publish annual reports and performance dashboards.

10. Manage change and stakeholders: Build consensus with trade unions, employees, consumers, the Ministry and political leadership through continuous communication and participation.

By adopting these measures, NEA can transform itself from a loss-making, politically influenced utility into a professionally managed, financially sustainable and customer-oriented enterprise.