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19 June 2019 MSB Presentation - Funders Workshop 3
INTRODUCTION
Market change drivers
1.Affordable tariffs
2.Become self-sufficient
possibility to export (jobs)
3.Encourage IPPs
4.Increase competition
5.Reduce need for GRN
financial support (equity /
loans / guarantees)
6.Increase access
7.Lights to stay on
8.Etc.
Why change?
Market Drivers (Bottom Up)
1.High and incorrect tariffs in combination with low cost new
technologies (SWH & PV) make it easy for customers to
reduce electricity purchases
2.It is happening as we speak, REDs and customers are
installing own generation (est. 50~60MW)
3.Customers are using services they are not paying for
(resulting in cross subsidisation)
4.Customers want services that the utilities don’t offer
5.Utilities losing sales, revenues and customers
6.Potential for stranded assets
7.Impede on efforts to increase access
8.Reduction in cost of storage will trigger customer defection
if utility is unable to meet customer needs.
9.Some customer want to purchase 100% renewable energy
10.Etc.
Policy Drivers (Top Down)
19 June 2019 MSB Presentation - Funders Workshop 4
INTRODUCTION
Market structure options
Market Drivers
(Bottom Up)
Policy Drivers
(Top Down)
New market design
Options Comments
Monopoly No longer a valid option for generation
SB Utility conflicts – not delivering on all policy objectives - not meeting customer needs
I(S)(M)(T)O High cost of restructuring – rationale should be clear – potential to swop one monopoly for another
MSB Managed approach towards more competition and customer participation while meeting policy objectives
Competition Very high cost of restructuring (breaking up NamPower)
Do nothing Death spiral
19 June 2019 MSB Presentation - Funders Workshop 6
TRADING ARRANGEMENTS
1a
Contestable Customers
MSB(SO/MO)
IPPs (Existing)
Imports (NP)
Generation (NP)
REDs, LA, & RC
Distribution Customers
Embedded IPPs
Exports (NP)
IPP
NP Tx Connected Customers
Captive Generation
Off-grid & mini-grids
Eligible Sellers
Exporter
Transactionall Flows from Seller to Buyer
Existing arrangementNew optional arrangement
19 June 2019 MSB Presentation - Funders Workshop 7
TRADING ARRANGEMENTS
1b
Contestable Customers
MSB(SO/MO)
IPPs (Existing)
Imports (NP)
Generation (NP)
REDs, LA, & RC
Distribution Customers
Embedded IPPs
Exports (NP)
IPP
NP Tx Connected Customers
Captive Generation
Off-grid & mini-grids
Eligible Sellers
Exporter
Trader Trader
Transactional Flows from Seller to Buyer
Existing arrangementNew optional arrangement
1. Phase 1a: Sep 2019 - June 2021; Tx Customers only
2. Phase 1b: July 2021 – June 2026; Tx + Dx ≥ 1MVA
3. Two stage approach to allow Distributors to unbundle sufficiently to enable wheeling
for their customers
4. Phase 2: July 2026 – onwards; Tx + Dx (as determined by Regulator); Imports
allowed
5. Imports only allowed from 2026 to support government policy of self-sufficiency and
to align with unwinding of current import contracts
19 June 2019 MSB Presentation - Funders Workshop 8
TRADING ARRANGMENTS
Phase 1 vs. Phase 2
19 June 2019 MSB Presentation - Funders Workshop 9
TRADING ARRANGEMENTS
2
Contestable Customers
MSB(SO/MO)
IPPs (Existing)
Imports (NP)
Generation (NP)
REDs, LA, & RC
Distribution Customers
Embedded IPPs
Exports (NP)
IPP
NP Tx Connected Customers
Captive Generation
Off-grid & mini-grids
Eligible Sellers
Exporter
Trader Trader
Transactional Flows from Seller to Buyer
Existing arrangementNew optional arrangement
Importer
19 June 2019 MSB Presentation - Funders Workshop 11
ELIGIBILITY CRITERIA
Summary
Phases1a
(1st Sep 2019 – June 2021)
1b
(July 2021 – June 2026)
2
(July 2026)
Contestable Purchases -National Cap
• 30% of total national purchases • 30% of total national purchases • As determined by Regulator
Contestable Purchases –Customer Supply Point Cap
• 30% of total customer purchase • For Distributors this volume is
reduced by 30% of the purchases by ≥1MVA connected customers
• As determined by Regulator • As determined by Regulator
Contestable Customers • Tx Connected
• Tx connected• Dx connected (≥1MVA)• Dx connected (<1MVA) as
determined by Regulator
• Tx connected• Dx connected (≥ 1MVA)• Dx connected (<1MVA) as
determined by Regulator
IPPs
• Licensed• Tx or Dx connected• Capacity ltd by sales to Contestable
Customers
• Licensed• Tx or Dx connected• Capacity ltd by sales to Contestable
Customers
• Licensed• Tx or Dx connected• Capacity ltd by sales to Contestable
Customers
Exporters• Licensed• No size limit
• Licensed• No size limit
• Licensed• No size limit
Traders• On application and approval by
Regulator; Licensed• No trading volume limit
• Licensed• No trading volume limit
• Licensed• No trading volume limit
Importers • Not allowed • Not allowed• Licensed• Capacity ltd by sales to Contestable
Customers
Focus:
• Examines the potential size of the contestable market
• Recommends level of contestability
Methodology:
• The Consultant worked with the ECB and NamPower to develop a forward view of the most likely energy sources for Namibia over the next 10 years
• The analysis divided the sources between:
– “Non-Displaceable”: There is a significant fixed cost (financial or contractual) associated with these sources. Not economic to displace.
– “Displaceable”: These sources have low or no fixed costs (or fixed cost could be avoided). These sources could be displaced at the right price or time
19 June 2019 MSB Presentation - Funders Workshop 13
SIZE OF CONTESTABLE MARKET
Focus & Methodology
• The figure on the right shows
the expected energy sources to
2026
• “Non-displaceable” sources
include:
–Existing Public
–Existing Private
–Committed Private
–Ministerial Determinations
–Existing Firm Imports
• “Displaceable” sources include:
–Flexible Imports
–New Supply
19 June 2019 MSB Presentation - Funders Workshop 14
SIZE OF CONTESTABLE MARKET
Definitions & Concepts
• The figure on the left shows the split between “Non-Displaceable” and “Displaceable” energy sources.
• “Displaceable” energy varies between 33-48% of total production.
• The figure on the right shows the total contribution (GWh) of “Displaceable” energy
19 June 2019 MSB Presentation - Funders Workshop 15
SIZE OF CONTESTABLE MARKET
”Displaceable” Energy Sources Potential
PRE-DISPATCH
19 June 2019 MSB Presentation - Funders Workshop 18
MARKET OPERATIONS
Trading Process
DISPATCH POST-DISPATCH
1. Seller and buyer enter into
bilateral
2. Seller meet requirements of
MSB
3. Submit data in accordance with
grid code
4. Specify nominated percentage
per customer
5. Notify MSB of any changes in
plant ability to meet schedule
6. MSB develop day-ahead hourly
demand forecast
7. Publish a day-ahead least-cost
Dispatch Schedule
1. Eligible Sellers dispatch their
plant in accordance with the
most recent Dispatch Schedule
2. The MSB adjust the output from
centrally dispatched units to
ensure that demand and supply
is balanced
3. Under certain Emergency
Conditions, instruct the Eligible
Producer to increase or
decrease output or to disconnect
from the grid
4. The MSB shall balance the total
integrated system in real time
1. MSB shall collect and record the
actual production
2. Once a month, the MSB shall
perform settlement functions
including meter reconciliation
and calculation of invoices
3. Disseminate relevant data to the
licensed distributors in order for
them to reconcile and settle
4. Review, and if needed, update
MSB Financial Security
requirements
5. Compare Delivered Energy from
every Eligible Seller against the
last Dispatch Schedule, adjusted
for Dispatch Instructions
6. Assess against balancing
mechanism/ determine
balancing energy
MARKET OPERATIONS
Balancing Mechanism
1. MSB will monitor scheduled production against actual production
2. A deviation away from scheduled position will attract a balancing payment
3. A tolerance band defined as lesser of:
a) ± 0.5MW, or
b) ± 2.5% of the plants last dispatch schedule
4. Balancing charge:
a) for negative deviations the charge will be set as a 100% of energy component of Bulk Supply Tariff
b) for positive deviations there will be no charge
5. Balancing payment (plus sale to bilateral customer) to pay for balancing the system
a) Only negative deviations will attract a balancing payment – no compensation for over generation
b) Deviations between the Lower and Upper limits do not attract a balancing payment
c) The bigger the deviation the higher the balancing payment
6. Financial Security will be placed with MSB for Balancing charges
19 June 2019 MSB Presentation - Funders Workshop 19
Deviation from Dispatch Schedule (MW/h)
0
Balancing Payment
Upper LimitLower Limit
19 June 2019 MSB Presentation - Funders Workshop 21
TARIFFS
Unbundled Services
Service Customers Generators
Energy (Utility) ✓ -
Less Wheeled Energy Rebate (✓) -
Wheeled Energy Addback (✓) -
IPP Purchases (✓)
Balancing - ✓
Tx/ Dx Use of System ✓ -
Tx/ Dx losses ✓ (✓)
Network Capacity Reserve - (✓)
Distributor Wheeling Charge (✓)* -
Reliability ✓* -
Net Billing (Banking/ Storage) - (✓)
Customer service ✓ ✓
Levies ✓* -
VAT ✓ ✓
19 June 2019 MSB Presentation - Funders Workshop 23
WHEELING
Simulated Wheeling Transaction in Model
19 June 2019 MSB Presentation - Funders Workshop 26
WHEELING TARIFFS
Potential Congestion scenarios and mitigations
Network congestion resulting inImpact Mitigation
Evacuation constraint
Delivery constraint
1 No No None • None
2 Yes NoSeller unable to produce energy and sell to Buyer
• Deemed payments in exchange for network capacity reserve charge
3 No YesSeller can produce but not sell to Buyer
The Seller may select one of the following prior to submitting the Day-ahead Production Schedules:
• The Seller could nominate an alternative Buyer for the unused power.
• MSB shall allow the Seller to “bank” the Unsold Energy. The Seller is allowed to withdraw the ‘banked’ power at a later stage in accordance with the rules of the Energy Banking Service.
• The customer may withdraw the stored energy when it is able to do so and subject to the Energy Banking Service conditions.
• Sell the unsold power to the MSB at a pre-arranged price.
4 Yes Yes
Seller unable to produce and sell and Buyer unable to purchase and consume
• Combinations of Options 2 or 3
• Licensing Applications and Processes currently being revised by ECB
• Licenses required for:
– Generation
– Transmission
– Distribution
– Import
– Export
– Trading
– Market Operations
• Market Participants will require multiple other approvals
– SO Approval; TNO Approval; MSB Approval & Registration; Other Permits/
Approvals
19 June 2019 MSB Presentation - Funders Workshop 28
APPROVALS
Will be aligned with requirements of the MSB
• Detailed design includes the following key design features:
– Planning Criteria/ Processes/ Responsibilities: Energy, Capacity, Ancillary
Services (ST, MT, LT)
– Conditions for NamPower to Act as Supplier of Last Resort (excl. for example
Exports and Imports)
– Call Back Option
19 June 2019 MSB Presentation - Funders Workshop 30
SECURITY OF SUPPLY
Detailed Design addresses Security of Supply issues
EXPORT “CALL-BACK”
How can Namibia protect its long term low cost resources
Depending on the situation (price, location, timing, etc.), Namibia may want to access some of thepower from the large and low-cost export orientated power generation projects. There are a few waysthrough which this can be achieved :
1. Purchase all the output from the plant.
Namibia can then use what it needs and
export the remaining power.
2. Purchase only a portion of the output. In this
way Namibia can access a specified quantity
of energy from the plant. The developer will
then be able to export the remainder of the
energy to its regional customer(s).
3. Incorporation of a ‘call -option’ in the power
purchase agreement between the IPP and
Namibia (represented by the MSB)
a) The price paid by the MSB shall be
equal to what the producer would have
received
b) Quantity of energy, exercised under the
call option, shall not exceed 20% of the
plant’s maximum total output (any 12
months)
After 1 yr notice = 3%
After 3yr notice = 10%
After 5yr notice = 20%
12 months min notice
1 yr 3 yr 5 yr
% of total
export
3119 June 2019 MSB Presentation - Funders Workshop
• Market Rules are under development and will be part of Grid Code
• Grid Code Advisory Committee (GCAC) is best positioned to assume the governance
roles and functions of the MSB
19 June 2019 MSB Presentation - Funders Workshop 33
GOVERNANCE
The GCAC is best placed to govern and implement the MSB
RISKS
Risks and Mitigations
Risks Mitigations
Cost of supply will increase (IPPs are expensive)
Appropriate procurement process and approval criteria by regulator (IPPs risk allocation)
Complexity (governance, trading, scheduling, dispatch and balancing)
Market rules, phasing, simplicity in design, monitoring and refinement
Viability of existing licensees (cherry-picking)Phasing, eligibility criteria and transparent subsidy framework
Additional resources needed to implement and operate new market structure
Simplicity in design and offset by market gains
New systems & processes Simplicity in design and offset by market gains
Network access, usage and paymentAppropriate connection, use of system and wheeling arrangements
Lights will go out (supplier of last resort)Revised planning procedures and adequacy criteria (ST, MT & LT)
Exporting low cost resources Call option
19 June 2019 MSB Presentation - Funders Workshop 35
19 June 2019 MSB Presentation - Funders Workshop
36
MARKET OPERATIONS
Balancing Mechanism Example (Under Delivery)
MSB
CusGen10 MW
1 MW
9 MW
MSB
CusGen1 MW @ PPA tariff
9 MW @ retail tariff8,5 MW @
balancing penalty
PHYSICAL FLOWS FINANCIAL FLOWS
= CONTRACTED ENERGY IN 1 HOUR
= DELIVERED ENERGY FROM ELIGIBLE SELLER
= DELIVERED ENERGY FROM SUPPLIER OF LAST RESORT (MSB)
= PAYMENTS ON ACTUAL ENERGY
= BALANCING PENALTY
19 June 2019 MSB Presentation - Funders Workshop
37
MARKET OPERATIONS
Balancing Mechanism Example (Over Delivery)
MSB
CusGen10 MW
10 MW
MSB
CusGen10 MW @ PPA tariff
5MW @ $0 balancing charge
PHYSICAL FLOWS FINANCIAL FLOWS
= CONTRACTED ENERGY IN 1 HOUR
= DELIVERED ENERGY FROM ELIGIBLE SELLER
= DELIVERED ENERGY FROM SUPPLIER OF LAST RESORT (MSB)
= PAYMENTS ON ACTUAL ENERGY
= BALANCING PENALTY
5 MW
• The concern is that the introduction of IPPs combined with the ability to wheel power could undermine the security of supply.
• This risk of inadequate supply over any planning horizon can be avoided by undertaking planning, scheduling and operating activities on a rolling basis, as well as by ensuring that appropriate adequacy criteria are employed.
• As the nominated supplier of last resort, many of these activities will be the responsibility of the MSB.
• MSB will not be required to act as Supplier of Last Resort on export transactions or import related purchases, unless negotiated
• The Reliability Service Charge will be used to compensate the MSB for acting as the Supplier of Last Resort
19 June 2019 MSB Presentation - Funders Workshop 40
SECURITY OF SUPPLY
Is supported by planning
Sufficient Energy Sufficient CapacitySufficient Ancillary
Services
• Well understood
• Currently managed by NIRP
• Need:
– regular updates
– to consider vRE
– to consider impact of net-metering & storage
• All of these issues can be addressed through planning
19 June 2019 MSB Presentation - Funders Workshop 41
SECURITY OF SUPPLY
Energy & Capacity Adequacy
MSB Supports Security of Supply via the following planning and operations
Long term plans 1-20 yrs
Annual Plans 12 months/ 52 week rolling
Weekly plans 4 weeks
Daily Schedules 24 hrs day ahead
Hourly operations Real time
• Given the increasingly important role that vRE is playing in electricity generation in
the region and the demands that this will place on ancillary services, it is expected
that the cost of providing these services will come under the spotlight.
• Several utilities including Eskom are reviewing their cost structures to better
understand the cost of providing these services.
• It is therefore reasonable to expect that ancillary services cost will be further
unbundled resulting in a substantial increase in the prices for the various services in
the near to medium term.
19 June 2019 MSB Presentation - Funders Workshop 42
SECURITY OF SUPPLY
Ancillary Services Adequacy
Operating Reserves
Spinning Reserves
Quick ReservesRegulating Reserves
Black Start & Islanding
Reactive Power & Voltage
ControlLoad following Other
• MSB must take pro-active stance on AS procurement, provision and payment
• MSB should develop an AS strategy
– clearly identify the need for ancillary services
– plan of who will provide these services
– and at what cost
• A system with very high levels of non-synchronous machines may experience a lack of reserves to deal with the system disturbances immediately following an incident (ltd inertia)
• Mitigation includes:
– Active power control services available to some types of vRE (e.g. wind generators can be designed to provide synthetic/pseudo inertia to the system. This means that inertia can be planned, controlled and optimised,
– Fast frequency response options such as energy storage systems and demand response.
– Regional interconnections provide access to larger network which will share the available inertia between the interconnected systems
• The above indicates that there is no natural or scientific ‘cap’ on the level of vRE in the system and that planning is needed to deal with the characteristics of new technologies
19 June 2019 MSB Presentation - Funders Workshop 43
SECURITY OF SUPPLY
Ancillary Services Procurement