Appendix a - Market Study

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East African Community (EAC)

Feasibility Study for aNatural Gas Pipeline fromDar es Salaam to Tanga(Tanzania) and Mombasa(Kenya)

Market Study

April 2011


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Market study-Natural Gas Pipeline from Dar to Mombasa

http://projects.cowiportal.com/ps/A005705/Documents/3 Project documents/4_Report/Phase3/P-073620-033.docx

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Table of Contents

List of Abbreviations and Units 21 Background 42 Scope of the project 52.1 Involved parties 52.2 Present infrastructure 62.3 Extension of pipeline 63 Dar es Salaam Market 83.2 Dar es Salaam Projection 103.3 Tanga market 113.4 Other domestic markets 113.5 Tanzania projection 113.6 Rakgas gas demand forecast Tanzania 124 Mombasa market 144.1 Power sector gas demand 144.2 Industrial gas demand 164.3 Mombasa projections 174.4 Rakgas gas demand forecast Mombasa 185 Gas production and demand 195.1 Gas production 195.2 Gas demand 196 References 22


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List of Abbreviations and Units

Abbreviations

AfDB African Development Bank

CNG Compressed Natural Gas

EWURA Energy and Water Utilities Regulatory Authority, Tanzania

ENPV Economic Net Present Value

ERR Economic Internal Rate of Return

FIRR Financial Internal Rate of Return

FNPV Financial Net Present Value

LNG Liquefied Natural Gas

NBV Netback Value

Orca Orca Exploration Group Inc.

PAT PanAfrican Energy Tanzania

Songas Songas Limited

TANESCO Tanzania Electric Supply Company

TPDC Tanzania Petroleum Development Corporation


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Volumes

scf Standard Cubic Feet

scfd Standard Cubic Feet per day

Mscf 10^3 Standard Cubic Feet

MMscf 10^6 Standard Cubic Feet

Bcf 10^9 Standard Cubic Feet

Nm^3 Normal Cubic Metre

1 scf 0.0268 Nm^3

1 scf 0.028 Sm^3

Energy

kW 10^3 Watt

1 kJ 1.055 BTU = 10^3 Joule

1 MJ 10^6 Joule

1 kWh 3.6 MJ

1 scf 1.025 BTU

1 Nm^3 39.9 MJ

1 Sm^3 36.35 MJ


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1 Background

This report is part of the Phase 2 outputs from the Feasibility Study for a Natu-

ral Gas Pipeline from Dar es Salaam to Tanga and Mombasa. The report com-

prises the output from Activities 4 and 7.

The potential demand is separated in demand for Dar es Salaam, demand for

Tanga, and demand for Mombasa.

The Dar es Salaam market is not relevant as such for the feasibility study of the

extension of the gas pipeline from Dar es Salaam to Mombasa. However, the

market study is used to determine if the there will be sufficient supply of gas

and capacity in existing (and decided) infrastructure, to cover the domestic de-

mand in Tanzania and expected exports to Kenya.

The market study for Dar es Salaam is mainly based on information from

EAC1, TPDC2, TANESCO3, Songas and ORCA Exploration Group4, as well asinformation from Energy and Water Utilities Regulatory Authority (EWURA).

So far there is only little information available about the potential demand in

Tanga, and no information about the potential demand in Arusha and Moshi.

The demand for Mombasa is mainly based on information from Ministry of

Energy and the Kenya LNG Study5and the Least Cost Power Development

Plan6.

The potential supply of gas from Songo Songo is based on information from the

operator of the gas field at Songo Songo7.

The Market Study was submitted to counterpart by end of October 2010 for

commenting. The comments received have been incorporated in this version.

1The East African Power Master Plan Study

2Pre-feasibility Study of Gas Pipeline Development, Rakgas Tanzania Limited, 25 Novem-

ber 2009 as well as power point presentation of potential gas demend in Tanzania3

TANESCO website4

Strategic Growth, Annual Report 2009, Orca Exploration Group Inc.5

Kenya LNG Study Phase 1Final Report, Ministry of Energy, Republic of Kenya 20106Least Cost Power Development Plan, Study Period 2010-2030, Ministry of Energy Kenya,

31 March 20107

See 4.

Gas demand

Gas supply

Comments from

counterparts


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2 Scope of the project

2.1 Involved parties

Tanzania Petroleum Development Corporation (TPDC), which is a state ownedcompany, owns the reserves in Songo Songo jointly with PanAfrican Energy

Tanzania (PAT). There is a Production Sharing Agreement (PSA) between

TPDC and PAT.

A proportion of the Songo Songo gas, called Protected Gas, is sold to Songas

Limited (Songas) under a 20 year gas agreement.

Songas Limited (Songas) is the owner of the wells, the gas processing plant and

the pipeline from Songo Songo to Ubungo. Songas is the operator of the high

pressure pipeline system and the Ubungo power plant. Shareholders of Songas

are Globeleq, TPDC, TANESCO, Tanzania Development Finance CompanyLimited (TDFL) and FMO from the Netherlands.

ORCA Exploration (Orca) operates in Tanzania through its wholly owned sub-

sidiary PanAfrican Energy Tanzania (PAT). Orca/PAT and TPDC have an ex-

clusive right to produce and market Additional Gas (see section 3.1.2), which is

all gas reserves from Songo Songo in excess of Protected Gas (see section

3.1.1). Orca/PAT has been contracted by Songas to operate the wells and the

gas processing plant and Orca/PAT owns and operates the gas distribution sys-

tem in Dar es Salaam (Ringmain).

Tanzania Electric Supply Company Limited (TANESCO) is a state ownedpower production, transmission and distribution company. TANESCO is share-

holder of Songas and buys electricity from the Songas owned Ubungo Power

Plant according to a Power Purchase Agreement. TANESCO also buys Addi-

tional Gas from Orca/PAT for operation of the TANESCO owned power plants

at Ubungo and Tagete.

Globeleq is the principal shareholder of Songas, through the financing subsidi-

ary Globeleq East Africa Capital Limited.


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2.2 Present infrastructure

2.2.1 Initial project

The gas is produced from the Songo Songo main field with an estimated re-

serve GIIP of 1345 Bcf by the end of 2009.

The infrastructure that processes and transports the gas from the Songo Songo

field to Ubungo near Dar es Salaam was commissioned in July 20048. The in-

frastructure comprises

a gas processing facility on Songo Songo with two gas processing

trains;

a 25 kilometres 12" offshore pipeline from the field to the SomangaFunga Landfall;

a 207 kilometres 16" onshore pipeline to the Ubungo power plant;

a 16 kilometres 8" lateral pipeline to the Wazo Hill cement plant.

The gas processing facility on Songo Songo has a capacity of 2* 35 MMscfd.

The original specifications of the pipeline from Songo Songo Island to Ubungo

would allow a capacity of approximately 65 MMscfd. During the development

Government of Tanzania decided to increase the dimension to allow for a ca-

pacity of 105 MMscfd. GOT borrowed USD 4.386 million from IDA to finance

the increase in pipeline capacity from Songo Songo to Ubungo (Over-sizing).

The low pressure distribution system comprises 50 kilometres of low pressure

pipeline in Dar es Salaam, four pressure reduction stations and two separate

connections to the 16" high pressure pipeline.

2.2.2 Expansion project

During 2009 Songas has proposed a new long term infrastructure expansion

project comprising two new gas processing trains and pipeline compression to

increase the throughput capacity to 144 MMscfd9.

2.3 Extension of pipeline

The scope of this study is the extension of the pipeline from Ubungo to Mom-

basa.

8Strategic Growth, Annual Report 2009, Orca Exploration Group Inc.

9Ibid p. 19

Reserves

Infrastructure

Distribution


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The problem about sufficient transport capacity from Songo Songo to Ubungo

will not be addressed in this feasibility study. In the report on "Methodology for

Financial and Economic Analysis" it is assumed that the gas transported toMombasa is charged a transport tariff for transport from Songo Songo to Ub-

ungo similar to the processing and transport tariff charged to Additional Gas.


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3 Dar es Salaam Market

The market in Dar es Salaam consists of power plants and industrial consumers.

In the following the demand in Dar is assessed with the purpose to identify as-

sumptions for the Mombasa market to be assessed in section 5.

The Dar es Salaam market is separated in Protected Gas and Additional Gas.

3.1.1 Protected gas

Under the Gas Processing and Transportation Agreement signed in 2001, the

Protected Gas from Songo Songo is sold under a 20 year gas agreement to Son-

gas for:

Operation of turbines at the Ubungo power plant (182MW);

Onward sale to the Tanzania Portland Cement Company (TPCC) for theoperation of kilns 2 and 3 at the Wazo Hill cement plant;

Electrification of villages along the pipeline.

The gas agreement is running from July 31, 2004 until July 31, 2024.

The consumption of Protected Gas is 80.5% of total gas consumption at the

Ubungo complex.

3.1.2 Additional gas

Additional gas is sold by Orca/PAT to:

Operation of turbines at the Ubungo power plant (42 MW);

Onward sale to TANESCO Ubungo power plant (102 MW) in opera-tion August 2008;

Onward sale to TANESCO Tegeta power plant (45 MW) commissionedin November 2009;

Onward sale to TPCC for operation of kiln 4 at the Wazo Hill cementplant in operation March 2009;


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Onward sale to 32 industries and 1 hotel by the end of 2009. About 10potential industrial customers are waiting for connection10.

The consumption of Additional Gas is 19.5% of total gas consumption at the

Ubungo complex.

By the end of 2009 there was 189 MW of installed gas fired generation in Tan-

zania that is being powered by Additional Gas.

Table 1 Assumptions for power sector gas demand in Dar es Salaam

Installed

capacity

Load

factor

Efficiency Commission

year

MW % %

Ubungo (Protected Gas) 185 77 40

TANESCO Ubungo 102 70 40 Jan 2009

TANESCO Tegeta 45 80 40 Oct 2009

Source: TANESCO and TPDC

3.1.3 Projections for the power sector

The power plant IPTL and Dowans are not converted to gas because of a dis-

pute11. We assume that IPTL will be connected in 2012 and Dowans two years

later in 2014. A new power plant Kinyerezi could be connected in 2017.

Table 2 Assumptions about power plants to be connected

Installed

capacity

Load

factor

Efficiency Assumed

connection

year

MW % %

IPTL 100 70 40 2012

Dowans 112 70 40 2014

Kinyerezi 240 70 34 2017

Source: TANESCO and TPDC

10Information from TPDC

11Strategic Growth, Annual Report 2009, Orca Exploration Group Inc.


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The connection years are based on the assumption that there will be financial as

well as labour force limitations to undertake several large infrastructure projects

at the same time.

3.1.4 Projections for industrial sector

TPDC has informed that about 10 potential industrial consumers are waiting for

connection12

Orca/PAT do not expect major increase in the number of industrial customers

but an increase in the demand from already connected customers.

Based on the application from Songas for an adjustment of the gas processing

and transportation tariff, EWURA13

made a forecast for industrial consumptionfrom 2010 to 2014.

3.2 Dar es Salaam Projection

We operate with 3 scenarios for Dar es Salaam.

Dar Low:

Power sector demand for gas until 2017 as described in section 3.1.3and then constant, i.e. further increases in electricity demand will be

based on hydro power and other fuels.

Industrial sector demand for gas until 2014 as described in section 3.1.4and then constant.

Dar Medium:

Power sector demand for gas until 2017 as described in section 3.1.3(same as for Dar Low) and then the demand will increase with an as-

sumed growth of 1% per year until 2035.

Industrial sector demand for gas until 2014 as described in section 3.1.4(same as Dar Low) and then the demand will increase with an assumed

growth of 1% per year until 2035.

Dar High:

Power sector demand for gas until 2017 as described in section 3.1.3(same as for Dar Low) and then the demand will increase with an as-

sumed growth of 2% per year until 2035.

12Information from TPDC

13Memorandum on Songas Processing and Transportation Tariff Adjustment, EWURA,

order No. 09-004.


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Industrial sector demand for gas until 2014 as described in section 3.1.4(same as Dar Low) and then the demand will increase with an assumed

growth of 2% per year until 2035.

The assumed growth rates are based on growth in the demand of gas of 1%

(medium) and 2% (high) per year. This does not mean that the growth in the

economy in general or in that region is limited to a growth of 1 or 2 %. An eco-

nomic growth in a region of 5-10% does not necessarily increase the gas de-

mand with 5-10%.

3.3 Tanga market

So far there is not much information about the potential market in Tanga. Ac-

cording to the Minutes of Meeting from the Inception meeting September 2010,TPDC has informed that the industrial market in Tanga is around 8-10 MMscfd

of which the cement plant will be the main consumer. EAC has in March 2011

informed about considerations of a new power plant of 100 MW in Tanga. Due

to the timing of this information the 100 MW are not included in the calcula-

tions.

3.4 Other domestic markets

Gas supply to the markets in Arusha and Moshi will depend on the feasibility

of the main pipeline from Dar es Salaam. The demands from the potential mar-

kets in Arusha and Moshi are estimated to be small and will not as such influ-ence the decision about implementing the main pipeline. The market in Baga-

moyo may be supplied depending on the routing of the main pipeline.

3.5 Tanzania projection

The total domestic demand for gas comprising Dar es Salaam and Tanga is pre-

sented below (excluding the plans on a new 100 MW power plant in Tanga).

Table 3 Potential gas demand in Dar es Salaam

2009 2035 Low 2035 High

MMscf MMscfd MMscf MMscfd MMscf MMscfd

Power sector 19,725 54 46,227 127 77,357 212

Industry 3,296 9 4,974 14 5,749 16

Total 23,021 63 51,201 140 83,106 228


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The daily demand is calculated as annual demand divided by 365. Songas is

currently processing and transporting up to 70 MMscfd of natural gas to mar-

kets in Dar es Salaam

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With a market in Tanga of approximately 10 MMscfd15 the total 2035 domestic

demand would be approximately 3,650 MMscfd (Low) and 6,108 MMscfd

(High).

3.6 Rakgas gas demand forecast Tanzania

In November 2009, Rakgas Tanzania Limited presented a pre-feasibility study16

comprising a projection of the gas market in Tanzania and Kenya.

Table 4 Rakgas/PDC gas demand forecast Tanzania

MMscfd

1 Songo Songo customers 160

2 Additional 300 MW near Dar 60

3 300 MW in Tanga 60

4 Additional industrial 15

Total 295

Comments:

Re. 1: It is not possible to identify the power plants included as Songo Songo

customers. An increase in gas consumption from 60 MMscfd to 160 MMscfd

should correspond to an increase of around 500 MW new power generation ca-

pacity. IPTL and Dowans are around 210 MW together, which leaves almost300 MW undocumented.

Re. 2: We believe that the additional 300 MW near Dar is the 250 MW in Kin-

yerezi.

Re. 3: The expected 300 MW thermal capacity in Tanga is not included in nei-

ther TANESCO planning nor EAC planning.

14Application to EWURA for approval of a revised gas processing and transportation tariff,

October 23, 2008.15Information from TPDC

16Pre-feasibility Study of Gas Pipeline Development, Processing, Transportation and Dis-

tribution: Tanzania. PDC - Rakgas Tanzania Limited, 25 November 2009.


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Re. 4: We find this a high estimate if it refers to additional industry but realistic

if it is total industry.

Reducing the Rakgas/PDC with 2*300 MW power generation capacity corre-

sponding to around 120 MMscfd results in a total demand of 175 MMscfd from

2017.

We have not made an appraisal of the Rakgas study but used it to double check

available information.


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4 Mombasa market

The basic source for information about the potential market in Mombasa is the

LNG study17 and the Least Cost Power Development Plan (LCPDP)18.

4.1 Power sector gas demand

4.1.1 Present potential gas demand

According to the LCPDP there are four existing power plants in the Mombasa

area that could be converted to gas. In addition one plant - Kipevu III - is ex-

pected to be commenced in 2011. The following general assumptions are made

about the power plants:

Table 5 Assumptions for power sector gas demand in Mombasa

Installed

capacity

Fuel type Load

factor

Efficiency Retirement

year

MW % %

Kipevu I 75 Diesel 80 40 2024

Kipevu II

Tsavo

74 Diesel 80 40 2019

Kipevu GT 60 Kerosene 80 40 2014

Rabai 90 Diesel 90 40

Source: Least Cost Power Development Plan, Ministry of Energy March 2010.

17Kenya LNG Study Phase 1Final Report, Ministry of Energy, Republic of Kenya 2010

18Least Cost Power Development Plan, Study Period 2010-2030, Ministry of Energy

Kenya, 31 March 2010


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4.1.2 Future potential gas demand

In addition to the commencement of Kipevu III in 2011, we assume that a new

capacity of 300 MW is installed in 2014 and further 300 MW in 2017.

A new 400 kV electricity transmission line is being constructed from Mombasa

to Nairobi. The line shall transfer electricity from thermal power plants in

coastal area to Nairobi. The power plants include the Kipevu III 120 MW as

well as a proposed 300 MW coal fired plant expected to be commenced in

2014. The transmission line is being financed by Government of Kenya, Afri-

can Development Bank, European Investment Bank and the French Develop-

ment Agency19.

The LCPDP have no details about the amount of conventional thermal power

plant to be built in the period 2010-2030. In section 5.5.4 it is mentioned thatgas turbines are modelled at an estimated cost of 833 USD/kW which is a com-

petitive unit cost compared to other thermal solutions. The LCPDP concludes

that "Though these plants have low initial capital outlay, they have high opera-

tional costs subject to fluctuations in international crude prices"20

It is assumed that the future value of CO2 emission will make electricity pro-

duced on natural gas competitive with electricity produced on coal and the 600

MW expected for Nairobi is included in the projection.

Table 6 Assumptions for new power plants in Mombasa area

Installedcapacity

Fuel type Loadfactor

Efficiency Commencingyear

MW % %

Kipevu III 120 Diesel 90 50 2011

New 1 300 Coal 90 50 2014

New 2 300 Coal 90 50 2017

19www.powergenworldwide.com August 2010

20Least Cost Power Development Plan, Study Period 2010-2030, Ministry of Energy Ke-

nya, 31 March 2010, page 66.


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4.2 Industrial gas demand

4.2.1 Present potential gas demand

According to the LNG study21 a number of large industries are identified as po-

tential gas customers. We assume that these industries can convert to gas rather

fast so they will be ready to connect when the gas is available in Mombasa.

Table 7 Fuel consumption in existing industries

Fuel type Unit Unit per year 2009

Athi River Ce-

ment

Coal Metric tons 125,000

Mabati Rolling

Mills

LPG Cubic metres 3,927

Mabati Rolling

Mills - heating

Electricity GWh 131

Bamburi cement

plant

Coal Metric tons 100,740

Milly Glass

Works

Diesel litres 5,666,667

Milly Glass

Works

LPG Cubic metres 2,655

Source: Kenya LNG study, 2010

4.2.2 Future potential gas demand

There have been significant variations in GDP in constant prices in Kenya dur-

ing the last 10 years. According to IMF the GDP growth in 2007 was 7.1%while the growth in 2009 was 2.5%. The real growth of GDP for 2010 is ex-

pected by IMF to be around 4%. The LNG study assumes that industrial con-

sumption will increase with 5% per year.

The LNG study operates with a low and a high case for industrial demand pro-

jection. The low case includes conversion of diesel and electricity consumers

mentioned industries. The high case includes conversion as in the low case

supplemented by the coal consumers. The LNG study assumes that the indus-

trial growth in the region will continue to grow at approximately 5% per year

21Kenya LNG Study Phase 1Final Report, Ministry of Energy, Republic of Kenya 2010


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which will be directly reflected in the consumption of end-users22. We find this

growth rate high as an average for the next 20 years and have reduced the rate

to 2% per year in our forecast.

We assume that all potential consumers mentioned in section 4.2.1 (also coal

fired) are converting to natural gas when available. After conversion we operate

with three scenarios as described in section 4.3. It is further assumed that poten-

tial industrial customers will be offered a discount in tariff to compensate for

conversion costs and provide an incentive (see the report Methodology for Fi-

nancial and Economic Analysis section 4.3).

4.3 Mombasa projections

We operate with 3 scenarios:

Mombasa Low:

Power sector demand for gas until 2017 will increase as described insection 5.1.2 (which includes the 600MW expected to be transported to

Nairobi) and then constant until 2035, i.e. the further increase in elec-

tricity demand will be covered by other sources than gas.

Industrial sector demand for gas comprises a conversion of the potentialdemand described in 4.2.2 and then constant.

Mombasa Medium:

Power sector demand for gas until 2017 will increase as described insection 4.1.2 (same as Mombasa Low) and then increase will an as-

sumed annual growth of 1% until 2035.

Industrial sector demand will be built up as described in section 4.2.2(same as Mombasa Low) and then increase with an assumed annual

growth of 1% until 2035.

Mombasa High:

Power sector demand for gas until 2017 will increase as described insection 4.1.2 (same as Mombasa Low) and then increase will an as-

sumed annual growth of 2% until 2035.

Industrial sector demand will be built up as described in section 4.2.2(same as Mombasa Low) and then increase with an assumed annual

growth of 2% until 2035.

22Kenya LNG Study Phase 1Final Report, Ministry of Energy, Republic of Kenya 2010,

page 54


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The 600 MW to be installed in the Mombasa area with export to Nairobi will

have an expected consumption of 33,000 MMscf or 90 MMscfd which is more

than half of the Mombasa low scenario power sector demand from 2017.

The 2009 figures in table 8 is what the demand would be if potential consumers

could connect to a gas pipeline.

Table 8 Potential gas demand in Mombasa

2009 2035 Low 2035 High

MMscf MMscfd MMscf MMscfd MMscf MMscfd

Power sector 19,008 52.1 56,188 153.9 94,027 257.6

Industry 6,167 16.9 6,167 16.9 10,321 28.3

Total 25,176 69.0 62,355 170.8 104,347 285.9

The daily demand is calculated as annual demand divided by 365.

Without the 600 MW power plant the low scenario demand would be reduced

to approximately 29,271 MMscf or 80.2 MMscfd in 2035.

4.4 Rakgas gas demand forecast Mombasa

In November 2009, Rakgas Tanzania Limited presented a pre-feasibility study23

comprising a projection of the gas market in Tanzania and Kenya.

Table 9 Rakgas/PDC gas demand forecast Kenya

MMscfd

Power sector 60

Industry 40

Total 100

Rakgas/PDC assumes that the planned 300 MW coal fired capacity will be re-

placed by natural gas.

The industrial demand is expected to be mainly from the cement factory.

23Pre-feasibility Study of Gas Pipeline Development, Processing, Transportation and Di-

stribution: Tanzania. PDC - Rakgas Tanzania Limited, 25 November 2009.


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5 Gas production and demand

5.1 Gas production

The operator Orca24 has informed that by 31December 2009 there was a pro-duction capacity of 217 MMscfd of which a required peak supply of approxi-

mately 45 MMscfd of Protected Gas.

Management's Best Case assessment of Gas Initially in Place is 1,571 Bcf for

the Songo Songo Field and Songo Songo North, with additional 727 Bcf in

Songo Songo West. In total approximately 2,300 Bcf25.

5.2 Gas demand

The total projected demand from Dar es Salaam and Mombasa for the period

2012 to 2035 is presented below.

Table 10 Total gas demand 2012-2035

Low Medium High

Bcf Bcf Bcf

Dar and Tanga 1,209 1,382 1,597

Mombasa 1,215 1,435 1,699

Total 2,424 2,817 3,295

Even with the low scenarios there will be a critical balance between potential

gas supply and potential demand. The low scenario will be reduced by ap-

proximately 662 Bcf if the 600 MW power capacity expected in Mombasa for

electricity supply to Nairobi is not connected to gas. In that case there would be

sufficient gas supply from Songo Songo. But with the information of the vast

24Strategic Growth, 2009 Annual Report, Orca Exploration Group Inc.

25Ibid


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gas reserves in Mnazi Bay there should be sufficient of gas to supply the de-

mand in all scenarios.

The demand in Dar es Salaam and Mombasa will at the project start be at the

same amount around 25,000 MMscf in each city, but the market in Mombasa

has a higher share of potential industrial consumers. In general industrial con-

sumers have a higher willingness to pay compared to the power sector, but

among the industries in Mombasa are industries that today use coal as fuel. In

the low scenario the demand from the power sector in Mombasa increases more

than the power sector in Dar es Salaam which is caused be an assumed connec-

tion of additional 720 MW. However, this increase is mainly caused by the 600

MW (33,000 MMscf) that is expected to supply Nairobi through the new

transmission line and these power plants are - so far - assumed by Government

of Kenya to be coal fired with a corresponding lower willingness to pay de-pending on the future price on carbon credits.

Figure 1 Gas market in Dar

-

20,000

40,000

60,000

80,000

100,000Dar Market, MMscf

Dar, Low growth (constant from 2017) Dar, 2% growth Dar, 1% growth


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Figure 2 Gas market in Mombasa

-

20,000

40,000

60,000

80,000

100,000

120,000

140,000

Mombasa Market, MMscf

Mombasa, 2% growth Mombasa, 1% growth Mombasa, low growth


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6 References

East African Community:

East African Power Master Plan

East African Community Secretariat, Report of the 17th Meeting of the Energy

Committee, Arusha, June 2010.

East African Petroleum Conference 2007: Songo Songo and Mnazi Bay Gas

Projects: Contribution to Economic Development, Eng. Joyce Kisamo, TPDC,

March 2007.

Kenya:

Kenya LNG Study, Phase 1 Final Report, Ministry of Energy, Republic of

Kenya, 2010.

Kenya Vision 2030, Sector Plan for Energy 2008-2012, Government of the Re-

public of Kenya, 2008.

Least Cost Power Development Plan, Study Period 2010-2030, Ministry of En-

ergy, Republic of Kenya, 2010.

Power Situation in Kenya, Hindpal S. Jabbal, Energy Regulatory Commission,

August 2009.

Tanzania:

Application to EWURA for approval of a revised gas processing and transpor-

tation tariff, 23 October 2008.

Memorandum on Songas Processing and Transportation Tariff Adjustment,

EWURA order No. 09-004.27 February 2009.

Pre-feasibility Study of Gas Pipeline Development, Rakgas Tanzania Limited,

25 November 2009


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Market study-Natural Gas Pipeline from Dar to Mombasa 23

Strategic Growth, Annual Report 2009, Orca Exploration Group Inc.

TANESCO website

Tanzania Gas Development and Utilization, Eng. Joyce Kisamo, Tanzania Pe-

troleum Development Corporation, 2009.

Tanzania Petroleum Development Corporation. The Export of Gas and Elec-

tricity from Tanzania to Kenya, Pre-Feasibility Study, February 1992.

TPDC power point presentations.