Project Presentation AMEU - Association of Municipal ... ABC (Aerial Bundle Conductor) / Underground...

Project Presentation AMEU

Masterplanning – (smart planning??) buzzword

or not …

What comes to your mind, where does it come to your

mind … water, roads, metering, infrastructure

Do you have a plan to succeed… do we plan, do we

(not) plan to fail ?

Is it better to have a good plan, a bad plan or no plan

at all …

▪ It‟s your choice

We have to plan … we do not want to fail

20 March 2013 AMEU / Windhoek 2

The deliverable should not just be a document, but added

value.

involvement –- (shareholders)

Includes being proactive and a catalyst to development – realizing that electricity is the DETERMINING KEY to development

To support REDS, town councils, communities and stakeholders to achieve their mission as set out by government e.g. vision 2030

To facilitate growth and development in all areas –

Get Town Councils involved for projects, coordination etc. with stakeholder, project (development funding), system upgrading … How can this be achieved – to finance ever increasing demand for

existing infrastructure – CAPEX, / Tariff, budgets ….

20 March 2013 3 AMEU / Windhoek

Challenges the ESI (Electricity Supply Industry) – is facing …

▪ Increased growth, demand on existing and aging infrastructure

– performance pressure from stakeholders

▪ Operation,

▪ maintenance,

▪ extension,

▪ rehabilitation and upgrading

Masterplan themes

▪ Benefits (why the Masterplan is needed)

▪ How is it approached, managed and produced

▪ Technical outlook and approach

▪ Economic analysis

▪ Financial analysis

▪ Qualitative report on social / economic issues


The deliverable should not just be a document, but added

value.

Masterplanning is an interactive engagement –

The project team (Owners/Champions) and Stakeholders (Town

Councils) need to interact with the consultants to enables mutually

agreeable projects and master plan guidelines –

Meetings and co-ordination will ensure elimination of

misunderstandings

Buy-in and support form stakeholders is essential


Requirements

to prepare an electricity distribution master plan for area(s) that are implementable,

sustainable and realistic, considering current constraints (and opportunities).…

Expectations

The existing infrastructure (of the towns) and expansion thereof has to be analysed –

in view of facilitating existing growth, a REASONABLE QoS (Quality of Supply)

and to sustain the continued electrification / servicing of PSA’s in the boundary of

the town

A key aspect to consider is the Town Planners ‘structure ‘master’ plan’ – assessing a

revised approach to the town‟s development

Above Master plan affects already electrified areas, as well as load / planning zones

in the town, hence the electricity distribution thereto.

Project parts

MV / LV Infrastructure assessment (in terms of carrying capacity / expandability /

suitability) and extension options … Electrification Planning for PSA / Informal

Settlement areas …


Criteria For Successful implementation

Cause and Effect Relationships:

• Every measure should be part of a “cause and effect” chain to determine if the measures correctly represents and drives the strategy.

Linked to Financials:

• Every measure selected should ultimately Drive Performance.

• Focus on factors that create long-term value.

Masterplan

Strategy

As-Is

To-Be

2012 2022


.


Masterplan Strategy

As-Is

To-Be

2012 2022

Interim Review

2015..7

What it is What it is not

An agreed roadmap of where

towards the infrastructure is to

develop

A concept and guide

A detailed reference manual

a „living‟ and „dynamic‟ reference

document

It is not a self-implementing

resource

It is not cast in stone

It cannot provide for all

circumstantial eventualities

The actual solution

The ultimate strategy

The fulfilled objectives

A Masterplan is very powerful when understood and used correctly


A clear set of agreed objectives will pave the way to a

successful Masterplan.

:

to have a technical philosophy with regard the MV and LV network

to have an assessment of the current status (As-Is)

to have a recommended network design (To-Be)

to have special projects and opportunities covered and identified

to have a plan for remedial works

to have cost estimates for all proposed works

to have a electrification plan for the Progressive Development Areas

to have Funding Request proposals


Focus on flood control,

area development –

Bigger flood control is

envisaged – relocation

of communities might

be envisaged, however

in the realistic context –

not very likely

View on 2050


Oshakati being a commercial developmental node

Accelerated institutional development

available information Spatial Development

plan Feeder Definition for

main town feeders – LPU (Large Power

User) Definition – for planning purposes


S-curve approach

(parameters) –

saturation of areas

Load-growth in an area

is saturable but not the

total area ► growth

and hence demand (not

necessarily affordability)

is not stoppable, and

will increase unhindered



Table 1: Growth/development Parameters –

Energy

Demand kWHr kVA Loadfactor

Energy Demand

Endavg (yr) 2012 4748515.00 9942.15 63%

Begin (Avg)2003 3407741.25 6827.64 66%

Growth (t_t) 1340773.75 3114.51 -3%

Months 108 108 108

Year 9 9 9

Growth/year 148974.86 346.06 0.00

% Growth 4.4% 5.1% -0.5%

y = 35.903x + 6488.7R² = 0.641

y = 14383x + 3E+06R² = 0.7448

0.00

1,000,000.00

2,000,000.00

3,000,000.00

4,000,000.00

5,000,000.00

6,000,000.00

0.00

2,000.00

4,000.00

6,000.00

8,000.00

10,000.00

12,000.00

14,000.00

10

/04

/20

03

10

/07

/20

03

10

/10

/20

03

09

/01

/20

04

08

/04

/20

04

09

/07

/20

04

08

/10

/20

04

10

/01

/20

05

08

/04

/20

05

08

/07

/20

05

10

/10

/20

05

10

/01

/20

06

10

/04

/20

06

10

/07

/20

06

10

/10

/20

06

10

/01

/20

07

10

/04

/20

07

10

/07

/20

07

10

/10

/20

07

10

/01

/20

08

10

/04

/20

08

10

/07

/20

08

10

/10

/20

08

09

/01

/20

09

09

/04

/20

09

31

/07

/20

09

31

/10

/20

09

31

/01

/20

10

30

/04

/20

10

31

/07

/20

10

31

/10

/20

10

31

/01

/20

11

30

/04

/20

11

31

/07

/20

11

31

/10

/20

11

31

/01

/20

12

OSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATIOSHAKATI

De

man

d

Demand and Energy Trends - OPE

Demand Billed

Units

Linear (Demand Billed)

Linear ( Units)


Town 2010 [kVA]

Energy % Demand % 2015 [kVA]

2020 [kVA]

Installed Supply [MVA]

TOTAL 30005 4.8% 4.6% 37885 46015

Assume 5% growth [Demand]) the following scenario

2016: 14MVA 2021: 18 MVA 2026: 23 MVA Vision 2030 as per semi industrialized

outlook - 30MVA BAR master plan – 2060: 130 MVA


Year MVA 2% 3% 4% 5% 6%

0 2011 11.00 11 11 11 11

1 2012 11.22 11.33 11.44 11.55 11.66

2 2013 11.44 11.67 11.90 12.13 12.36

3 2014 11.67 12.02 12.37 12.73 13.10

4 2015 11.91 12.38 12.87 13.37 13.89

5 2016 12.14 12.75 13.38 14.04 14.72

6 2017 12.39 13.13 13.92 14.74 15.60

7 2018 12.64 13.53 14.48 15.48 16.54

8 2019 12.89 13.93 15.05 16.25 17.53

9 2020 13.15 14.35 15.66 17.06 18.58

10 2021 13.41 14.78 16.28 17.92 19.70

11 2022 13.68 15.23 16.93 18.81 20.88

12 2023 13.95 15.68 17.61 19.75 22.13

13 2024 14.23 16.15 18.32 20.74 23.46

14 2025 14.51 16.64 19.05 21.78 24.87

15 2026 14.80 17.14 19.81 22.87 26.36

16 2027 15.10 17.65 20.60 24.01 27.94

Year MVA 2% 3% 4% 5% 6%

0 2011 11.00 11 11 11 11

5 2016 12.14 12.75 13.38 14.04 14.72

10 2021 13.41 14.78 16.28 17.92 19.70

15 2026 14.80 17.14 19.81 22.87 26.36

20 2031 Vision 2030 16.35 19.87 24.10 29.19 35.28

25 2036 18.05 23.03 29.32 37.25 47.21

30 2041 19.92 26.70 35.68 47.54 63.18

35 2046 22.00 30.95 43.41 60.68 84.55

40 2051 24.29 35.88 52.81 77.44 113.14

45 2056 26.82 41.60 64.25 98.84 151.41

50 2061 29.61 48.22 78.17 126.14 202.62

TOWN 2001 2011 Increase

Oshakati 28255 35600 26%

Windhoek 233529 322500 38.1%

Ongwediva 10742 19300 79.7%

Ondangwa 10900 21100 93.6%

TOWN 2001 2011 Increase

Oshakati 28255 35600 26%

Windhoek 233529 322500 38.1%

Ongwediva 10742 19300 79.7%

Ondangwa 10900 21100 93.6%

planned investment to have a backup-and secure supply to the town

NamPower developments in the medium term

Options for implementation, plan to implement in the short term the following –

Main Supply and Backup Supply to OPE with a second infeed station to the grid –

Each Supply point should have an alternate supply route from NamPower (if possible)


NamPower Supply options –

Redundancy / Backup – where is the critical point?

Capacity (short and medium term)

Costs

Limitations

Outlook

Quality of Supply (and Service)

How can REDs afford this ….

▪ We get to this a little later


Need a scientific

approach with

high reliability for

planning

Feeder scaling –

Loads

Redundancy

scenarios


CURRENT MAIN STATION FEEDERS

LPU CLIENT PROFILES


0

2000

4000

6000

8000

10000

12000

00:3

0

01:3

0

02:3

0

03:3

0

04:3

0

05:3

0

06:3

0

07:3

0

08:3

0

09:3

0

10:3

0

11:3

0

12:3

0

13:3

0

14:3

0

15:3

0

16:3

0

17:3

0

18:3

0

19:3

0

20:3

0

21:3

0

22:3

0

23:3

0

Dem

and

[kVA

]

Town Feeders - OPE 13 Sep 2011

Industrial

Oshakati West

Town 1

Town Feeder

TOTAL

Current main station feeders

0.0

500.0

1000.0

1500.0

2000.0

2500.0

3000.0

0.0

200.0

400.0

600.0

800.0

1000.0

1200.0

1400.0

1600.0

00:3

0

01:3

0

02:3

0

03:3

0

04:3

0

05:3

0

06:3

0

07:3

0

08:3

0

09:3

0

10:3

0

11:3

0

12:3

0

13:3

0

14:3

0

15:3

0

16:3

0

17:3

0

18:3

0

19:3

0

20:3

0

21:3

0

22:3

0

23:3

0

Dem

and

[kV

A]

LPU - OPE

NamWater

Meatco

Game

CocaCola

Etango

TOTAL

Load centres / Distribution centres / policies

Main Load centres (Primary Stations) direct feed

Distribution centres – to feed into rings

Stations – 2500A Busbars / fault levels .... >20kA .. 31,5kA (11kV) - decisions

– 1250 A Breakers / feeders / 2 bus-sections


15 .. 25 MVA –

load scaling

Voltage profile

problems


Load-flow

assessments

Feeder loading /

profile

Voltage profile

Protection

coordination –

was done (can

be provided as

backup support

to the MP)


Infeed % of % of % of % of % of % of

Year MVA % Town total load OPE total load Oneshila total load Industrial total load Oshakati West total load Town 2 total load

2011 10.210 100.00% 0.400 3.92% 0.100 0.98% 2.600 25.47% 3.150 30.85% 2.090 20.47% 1.870 18.32% 10.210 100%

15.000 146.91% 0.588 3.92% 0.147 0.98% 3.820 25.47% 4.628 30.85% 3.071 20.47% 2.747 18.32% 15.000 100%

20.000 195.89% 0.784 3.92% 0.196 0.98% 5.093 25.47% 6.170 30.85% 4.094 20.47% 3.663 18.32% 20.000 100%

UPGRADE PATH

Overhead / underground (cables, monopole, concrete, lattice?)

Switchgear – SF6? / oil / vacuum LV ABC (Aerial Bundle Conductor) / Underground Street lighting and HML (High Mast Lighting) Metering

COSTING / LOAD TRANSFER


Figure 1 : Technology options – feeder comparison

Cost/capacity comparison Cost [N$/m] Rating [A] ratio

Overhead line

Gopher: 11/22/33kV - 80.00$ 150

Rabbit: 11/22/33kV - 100.00$ 240 22%

Hare: 11/22/33kV - 120.00$ 360 15%

underground cable

70mm2 Cu XLPE TypeA 450.00N$ 240





Overhead is only + - 20% of the cost of underground

NO

RT

H –

SO

UT

H A

XIS

UP

GR

AD

E


Priority / Technology.

OPE Cost Estimate for new Stations - N/S connection for Load Centres

150mm2 Cu XLPE Cable

Distance (m) Cost/Unit SubTotal Total

3600 N$ 700.00 N$ 2,520,000.00 N$ 12,096,000.00

Stations x2 N$ 4,000,000.00 N$ 8,000,000.00 N$ 8,000,000.00

Grand Total N$ 20,096,000.00


Project Components MV & LV projects

Special

PDA Electrification

CAPEX projects ..\Technical Info\Project Costing\OPE_TOWN-Infrastructure_CAPEX

OPEX 21Apr2012 R3.xlsx

All projects are identified for implementation, with a total CAPEX of N$ xxx

Million. Implementation has to be assessed in line with revised (dynamic) development requirements.

Security, QoS and related issues are addressed ….

OPE (Oshakati

Premier Electric)

CAPEX Infrastructure

requirement

Special OPE Projects on

DSM/Metering/Control

and NAMPOWER

Contribution

MV Masterplan Upgrade Maintenance Medium

Voltage (11/22/33kV)

Maintenance LV (Low

Voltage 230/400V)

PDA (Progressive

Development Areas)

projects

Total per FY

Year 1 Financial year 2010/11 N$ 1,000,000.00 N$ 10,407,840.00 N$ 441,500.00 N$ 420,120.00 N$ 2,152,888.89 N$ 14,422,348.89

Year 2 Financial year 2011/12 N$ - N$ 4,690,000.00 N$ 240,000.00 N$ 370,160.00 N$ 1,288,888.89 N$ 6,589,048.89

Year 3 Financial year 2012/13 N$ 3,000,000.00 N$ 3,735,840.00 N$ 500,900.00 N$ 99,367.20 N$ 734,400.00 N$ 8,070,507.20

Year 4 Financial year 2013/14 N$ 47,000,000.00 N$ 1,687,200.00 N$ 4,960,500.00 N$ 87,212.00 N$ 2,402,666.67 N$ 56,137,578.67

Year 5 Financial year 2014/15 N$ 28,000,000.00 N$ 3,682,500.00 N$ 269,400.00 N$ - N$ 1,991,111.11 N$ 33,943,011.11

Year 6 Financial year 2015/16 N$ - N$ 5,360,000.00 N$ - N$ 4,438.40 N$ - N$ 5,364,438.40

Year 7 Financial year 2016/17 N$ - N$ 3,463,360.00 N$ - N$ - N$ - N$ 3,463,360.00



Year 10 Financial year 2020/21 N$ 25,000,000.00 N$ 10,633,600.00 N$ - N$ - N$ - N$ 35,633,600.00

N$ 104,000,000.00 N$ 59,298,860.00 N$ 6,412,300.00 N$ 981,297.60 N$ 8,569,955.56 N$ 179,262,413.16

NamPower Contributionfor Intake 2 not included

- but highlighted

../Technical Info/Project Costing/OPE_TOWN-Infrastructure_CAPEX OPEX 21Apr2012 R3.xlsx













SPECIAL CAPEX PROJECTS

Ekuku 4 MVA application Funded from NETWORK CONTRIBUTION ....

BY WHOM / FOR WHOM … WHAT IF NOT..


-

2,000,000.00

4,000,000.00

6,000,000.00

8,000,000.00

10,000,000.00

12,000,000.00

1 2 3 4 5 6 7 8 9 10

OPEX Infrastructure requirement: Oshakati [NPV] - Special Projects

CAPEX Infrastructure requirement: OPE

(Oshakati Premier Electric)

Table 1: OPE CAPEX projects – Special Projects

OPE (Oshakati Premier Electric) Special projects - OPEX Infrastructure requirement

Network Re-enforcement task

Prio

rity

[1

=h

igh

,

2-m

ed

ium

, 3=

low

] Attribute Rate Cost Year PIP

1 DSM (Demand Side Management) Intervention Ripple control to manage Loads / Load shifting / HVAC control options

2 Special OPEX

$ 3,000,000.00 $ 3,000,000.00 3

2 AMR (Automatic Metering & Billing System) - route on smart (knowledge based) grid - convert all meters to ToU (Time of Use Tariffs) - in phases from LPU / 3 Phase - with options to later place Single Phase customers and PPM on ToU

1 Special OPEX

$ 1,000,000.00 $ 1,000,000.00 1

3 SCADA project - Grid Automation (preliminary)

1 Special OPEX

$ 1,000,000.00 $ 1,000,000.00 5

4 Allow for NamPower Contribution for Second 20 MVA transformer at the Intake Station PART 1 - Sinking Fund

1 Special OPEX

$ 5,000,000.00 $ 5,000,000.00 4

5 Allow for NamPower Contribution for Second 66kV Supply to intake station from Makalani Part 1 Sinking Fund

3 Special OPEX

$ 5,000,000.00 $ 5,000,000.00 5

6 Allow for NamPower Contribution for Second 66kV Supply to intake station from Makalani Part 1& 2 - Sinking Fund

3 Special OPEX

$ 10,000,000.00 $ 10,000,000.00 10

$ 25,000,000.00

NamPower contribution / sinking funds for 20-30 Million has to be accommodated, and to be worked into the tariffs, alternatively the financing thereof.. –

AD-HOC ACCELERATION

Projects

Budgets

Priorities KEY TABLE – infrastructure action plan ….

Technologies

Total budget – tba

Estimate xxx Million for 10 years

Projects listed as referenced


OPE (Oshakati Premier Electric) CAPEX Infrastructure requirement

Drawing Ref. No

Network Re-enforcement task

Prio

rity

[1=h

igh,

2-m

ediu

m, 3

=low

] Source / From Destination / To / at Node

Cost Year PIP

1 Build a Second Intake Station - NamPower OPE Intake No. 2

3 Nampower/OPE Etango/OPE01 $ 400,000.00 6

1A Equip Station NamPower OPE No 2. with metal-clad 2500A 11kV circuit breakers / and ancillary equipment

3 Nampower/OPE Etango/OPE01 $ 3,600,000.00 6

1B Build a Second Intake Station - NamPower OPE Intake No. 1 adjacent to existing OPE current Intake, - OPE Main Intake 1


1C Convert Existing OPE Intake to OPE 1 Distribution Station


2 Build CBD/Etango Distribution Station

1 OPE01/OPE02 Etango $ 400,000.00 1

2A Equip CBD Etango Station with metal-clad 2500A 11kV circuit breakers / and ancillary equipment

1 OPE01/OPE02 Etango $ 4,050,000.00 1

2B Install MV feeder line from NamPower OPE Intake Station 1 to Etango DS - (2 x150mm Cu XLPE)

1 Intake 01 Etango/OPE02 $ 3,191,600.00 1

2C Install MV feeder from Intake Station 1 to Etango DS - (2 x150mm Cu XLPE)


3 Install MV feeder from Intake Station 2 to Etango DS - (2 x150mm Cu XLPE)


3A Install MV feeder from Intake Station 2 to Etango DS - (2 x150mm Cu XLPE)


4 Upgrade Oneshila Switching Node to a full DS: Oneshila DS

1 Intake 01 Oneshila DS $ 3,500,000.00 2

5 Install MV feeder from Intake Station 1 to Oneshila DS - (150mm Cu XLPE)

1 Intake 01 Oneshila DS $ 1,266,400.00 3

6 Install MV feeder from Nampost Overhead line to Bank of Namibia Trf - (120mm Cu XLPE)

1 Intake 01 Oshakati East $ 1,045,200.00 3

7 Install a 4-way RMU at the Bank of Namibia

2 Intake 01 Oshakati East $ 90,000.00 4

7A Connect Town Council RMU from new RMU - (120mm Cu XLPE)

2 Intake 01 Oshakati East $ 264,000.00 4


TOTAL N$ 221,495,497.80

excl. Nampower

TOTAL N$ 179,262,000.-

Incl NamPower

Excl.

N$ 79,262,000.-

QoS

DSM

RE‟s

PFC

PDA Electrification


QoS….

Where are we ….

We have sophisticated clients

Commodity labeling in terms of QoSS

… ( )

Quality awareness – linked to

performance and cost/value


Limited option – Profile excellent for RE PV input (Northern Namibia)

Cost kWHr at ND 2.20 – maybe at 1ND in future – (Large PV stock in Europe / costing weights

on technology and inverter equipment)

Incentives – Tariff and Pricing signal

Implement the AMR (Automatic Metering & Billing System) and ToU (Time of Use Tariffs)

allowing customers to benefit from scheduling the load (off from peak) – and the tariff to be

structures such that OPE does NOT have less revenue – but MORE capacity (aim – deferred

investment is seen as saving). – PROVIDE A TARIFF (AND SOLUTION) FOR THE VOLUME..

Ordinary People do not have a choice (and benefit) on ToU

PV Large scale

OPE plan, NamPower plan ... PV plans coming (3 x 10 MW PV input) / Concentrated PV (REEE)

– profile allows grid in-feed for standard and peak tariff times in-feed (Winter and Summer /

except when overcast – which is not the case in Winter) ? – Industry players – accommodating

private small, medium and large partners

Controllable loads –

Smart cooling systems can be implemented – HVAC

Geyser penetration assessment – limited (estimate OPE ... 2000 controllable loads / others)

All new developments (medium / high) income will have HWS – Solar be recommended

Benefit in load shifting – not necessarily Maximum Demand


Customer / client base categories – based on number of customers per category and reference to

residential load profiles Source: OPE (Oshakati Premier Electric) Nena asset register / energy sales/PCE (PowerConsult Engineers)

METER AUDIT Data – and NENA 2012 data (OPE/Emcon)


4,040

107

252121

70

Oshakati Customer Profile and Base [est 2011 /

based on NENA 2011 and Meteraudit 2008]

Sum of PPM 1 phase

Sum of PPM 3 phase

Sum of BUS-1

Sum of BUS-3

Sum of LPU

0

1000

2000

3000

4000

5000

6000

7000

8000

9000

1000030

/08/

2011

00:

00

30/0

8/20

11 0

1:00

30/0

8/20

11 0

2:00

30/0

8/20

11 0

3:00

30/0

8/20

11 0

4:00

30/0

8/20

11 0

5:00

30/0

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11 0

6:00

30/0

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11 0

7:00

30/0

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11 0

8:00

30/0

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11 0

9:00

30/0

8/20

11 1

0:00

30/0

8/20

11 1

1:00

30/0

8/20

11 1

2:00

30/0

8/20

11 1

3:00

30/0

8/20

11 1

4:00

30/0

8/20

11 1

5:00

30/0

8/20

11 1

6:00

30/0

8/20

11 1

7:00

30/0

8/20

11 1

8:00

30/0

8/20

11 1

9:00

30/0

8/20

11 2

0:00

30/0

8/20

11 2

1:00

30/0

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11 2

2:00

30/0

8/20

11 2

3:00

31/0

8/20

11 0

0:00

31/0

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1:00

31/0

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2:00

31/0

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3:00

31/0

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4:00

31/0

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5:00

31/0

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6:00

31/0

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7:00

31/0

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8:00

31/0

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9:00

31/0

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0:00

31/0

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11 1

1:00

31/0

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11 1

2:00

31/0

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11 1

5:00

31/0

8/20

11 1

6:00

31/0

8/20

11 1

7:00

31/0

8/20

11 1

8:00

31/0

8/20

11 1

9:00

31/0

8/20

11 2

0:00

31/0

8/20

11 2

1:00

31/0

8/20

11 2

2:00

31/0

8/20

11 2

3:00

Axi

s Ti

tle

OPE Daily Profile

KW

KVAR

KVA

Considered DSM Demand reduction

Load shifting (HVAC/ Geyser_

Tariff signals

CAPEX >3-4 Mio

Payback 4-6 yrs

Benefit: YES

Explore add. Options

NamPower Better negotiated tariffs

on capacity shedding

with NamPower

..\Technical Info\DSM\DSM OPE

assessment OPE EMP

R1.xlsx


DSM considerations - OPE EMP (OPE Electrical MasterPlan)

Geyser penetration 40%

Households/total TOTAL HHlds

Households with geysers 4292 HHlds

Controlloabel loads (HVAC) 480 Buss/HHls

40% HHlds with geysers

20% HHLds with HVAC

2kW/Element 3433.52 kW 2 kW/geyser

Controlable loads 1373.408 KW 40%

2kW compressor 191.84 kW 2 kW./ HVAC

HVAC 95.92 kW 50%

3 hours Energy Shift 2 hrs a.m ./ 1 hr p.m.

4407.984 kWHr/day

Winter (3 months)

Demand [kVA]: 0 39.55N$ -N$

Energy: Peak 1.66N$ (allow only DEMAND - not CAPACITY ACCESS)

Standard 0.69N$

(evening only) Offpeak 0.34N$ (excluded)

Saving 0.97N$ Peak -> Standard

4,275.74N$ /day

days/month 30 128,272.33N$ /month

Total 128,272.33N$ /month

384,817.00N$ / 3 month

Summer (9 months)

Demand [kVA]: 0 39.55N$ -N$

Energy: Peak 0.71N$ (allow only DEMAND - not CAPACITY ACCESS)

Standard 0.57N$

(evening only) Offpeak 0.31N$ (excluded)

Saving 0.14N$ Peak -> Standard

617.12N$ /day

days/month 30 18,513.53N$ /month

Total 18,513.53N$ /month

166,621.80N$ /9 month

Annual estimated saving: Winter 384,817.00N$

(Demand and Sales) Summer 166,621.80N$

551,438.80N$

Saving in terms of payment to NamPower -

../Technical Info/DSM/DSM OPE assessment OPE EMP R1.xlsx















Already implemented

(reduce MD by 1 MVA)


Past achievements

for OPE

Over the last 12

years a major focus

on PDA electrification

– and HML (High

Mast Lighting) has

been exhibited by

OPE

Additional major

shopping areas and

institutional

developments have

materialized –

resulting in system

growth


HES of electrified and un-electrified area ... Know and Discover the benefit


Ompumbo – un-electrified

Evululuko - Electrified

n

Low High Financial

Low

High

Quantifiable

Financial & Quantification:

RoI, IRR, NPV of the project,

Unlocking the value of existing isolated

Infrastructure,

Low Financial & Quantification:

Increased literacy,

Possibility of distance education,

More homes with electricity,

Increased empowerment of females,

Low Financial & Low Quantification:

Increased business in another

locations as a result of local activities,

Reduction of solar theft,

Quicker deployment of telecommunications

Infrastructure,

Increased standard of living,

Reduced deforestation,

Improved health care facilities,

E-government opportunities,

Poverty reduction,

Financial & Low Quantification:

Increased economic activity due to

electricity,

Development of „Green Schemes‟,

Increased Tourism activities,

Job creation,


Capital Portfolio

40%

30%

10%

15%

5%Baseline Electrification

Backbone Infrastrucure

Rural/Informal Settlement

Electrification

Efficiency and

Effectiveness

Support

Projects categorization

Infrastructure projects – those that have to be done

Development projects – those that should be done on merit. (PDA / SL)

Financing

ADB, DBN ... interested / Electrical business is very viable … BUT...

Finance options ... Smart partnerships ... (can you find them?)

Capital Appropriation

Need more intense discussions on how to allocate budgets/ source of

funding


Grant Funding: 40%

Remainder: 60% through commercial bank loan

Conclusion: All projects feasible

Annual Revenue: N$2.4 million

CAPEX years 0-5: N$8.5 million

CAPEX years 5-10: N$0 million

CAPEX years 10-15: N$0 million

Total CAPEX: N$8.5 million


Reference /

map

[D

om

inant]

Nam

e

per m

onth

purchases

[P

resent]

yr 0 - 5

yr 5 - 10

yr 10 - 15

yr 0 - 5

yr 5 - 10

yr 10 - 15

counted no. of

erven

deriv

ed / on

density

NP

V

IR

R

E1 Residential Ompumbu 24 260.00N$ 1 078 222.22N$ -N$ -N$ 54 0 0 108 Project 1 333 003.17N$ 18.7%

E2 Residential Ompumbu 24 180.00N$ 1 074 666.67N$ -N$ -N$ 54 0 0 107 Project 2 331 905.05N$ 18.7%

R Residential Oshimbangu 29 000.00N$ 1 288 888.89N$ -N$ -N$ 64 0 0 129 Project 3 398 066.44N$ 18.7%

T3 Residential Evululuko 27 540.00N$ 734 400.00N$ -N$ -N$ 55 0 0 61 Project 4 519 722.22N$ 44.3%

U5 Residential Kandjengedi South 54 060.00N$ 2 402 666.67N$ -N$ -N$ 120 0 0 240 Project 5 742 050.75N$ 18.7%

X Residential Onawa 44 800.00N$ 1 991 111.11N$ -N$ -N$ 100 0 0 199 Project 6 614 944.02N$ 18.7%

2 446 080N$ 8 569 956N$ -N$ -N$

Projects will have to be prioritized on merit. This can include socio-economic

aspects, political aspects, or other non-financial and possibly non-quantifiable

considerations.

These will typically be more favorably be assessed by Development Agencies

than commercial loan institutions.

Funding for electricity projects can come from various sources.

Options include: Self-financed

Donor agencies

Government Development Funds

Commercial loans

Capital contribution

TARIFFS … or … we are all challenged here



End

Project Presentation AMEU - Association of Municipal ... ABC (Aerial Bundle Conductor) / Underground...

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